Science.gov

Sample records for retorted shale stress

  1. RETORT. Oil Shale Retorting Simulation

    SciTech Connect

    Eyberger, L.R.

    1992-02-26

    RETORT is a one-dimensional mathematical model for simulating the chemical and physical processes involved in the vertical retorting of a fixed or moving rubbled bed of oil shale. The model includes those processes believed to have the most important effects in either the hot-gas retorting mode or the forward combustion retorting mode. The physical processes are: axial convective transport of heat and mass, axial thermal dispersion, axial pressure drop, gas-solid heat transfer, intraparticle thermal conductivity, water evaporation and condensation, wall heat loss, and movement of shale countercurrent to flow of gas. The chemical reactions within the shale particles are: release of bound water, pyrolysis of kerogen, coking of oil, pyrolysis of char, decomposition of carbonate minerals, and gasification of residual organic carbon with CO2, H2O, and O2. The chemical reactions in the bulk-gas stream are: combustion and cracking of oil vapor, combustion of H2, CH4, CHx, and CO, and the water-gas shift. The RETORT model is meant to simulate adiabatic laboratory retorts and in situ retorts that have been prepared with fairly uniform lateral distribution of shale particle sizes, void volume, and permeability. The model`s main role is to calculate, as a function of time and axial location in the retort, the flow rate of the bulk-gas stream and the composition and temperature of both the fluid stream and the shale particles.

  2. RETORT. Oil Shale Retorting Simulation

    SciTech Connect

    Braun, R.L.

    1992-02-26

    RETORT is a one-dimensional mathematical model for simulating the chemical and physical processes involved in the vertical retorting of a fixed or moving rubbled bed of oil shale. The model includes those processes believed to have the most important effects in either the hot-gas retorting mode or the forward combustion retorting mode. The physical processes are: axial convective transport of heat and mass, axial thermal dispersion, axial pressure drop, gas-solid heat transfer, intraparticle thermal conductivity, water evaporation and condensation, wall heat loss, and movement of shale countercurrent to flow of gas. The chemical reactions within the shale particles are: release of bound water, pyrolysis of kerogen, coking of oil, pyrolysis of char, decomposition of carbonate minerals, and gasification of residual organic carbon with CO2, H2O, and O2. The chemical reactions in the bulk-gas stream are: combustion and cracking of oil vapor, combustion of H2, CH4, CHx, and CO, and the water- gas shift. The RETORT model is meant to simulate adiabatic laboratory retorts and in situ retorts that have been prepared with fairly uniform lateral distribution of shale particle sizes, void volume, and permeability. The model`s main role is to calculate, as a function of time and axial location in the retort, the flow rate of the bulk-gas stream and the composition and temperature of both the fluid stream and the shale particles.

  3. Solar retorting of oil shale

    DOEpatents

    Gregg, David W.

    1983-01-01

    An apparatus and method for retorting oil shale using solar radiation. Oil shale is introduced into a first retorting chamber having a solar focus zone. There the oil shale is exposed to solar radiation and rapidly brought to a predetermined retorting temperature. Once the shale has reached this temperature, it is removed from the solar focus zone and transferred to a second retorting chamber where it is heated. In a second chamber, the oil shale is maintained at the retorting temperature, without direct exposure to solar radiation, until the retorting is complete.

  4. Oil shale retort apparatus

    DOEpatents

    Reeves, Adam A.; Mast, Earl L.; Greaves, Melvin J.

    1990-01-01

    A retorting apparatus including a vertical kiln and a plurality of tubes for delivering rock to the top of the kiln and removal of processed rock from the bottom of the kiln so that the rock descends through the kiln as a moving bed. Distributors are provided for delivering gas to the kiln to effect heating of the rock and to disturb the rock particles during their descent. The distributors are constructed and disposed to deliver gas uniformly to the kiln and to withstand and overcome adverse conditions resulting from heat and from the descending rock. The rock delivery tubes are geometrically sized, spaced and positioned so as to deliver the shale uniformly into the kiln and form symmetrically disposed generally vertical paths, or "rock chimneys", through the descending shale which offer least resistance to upward flow of gas. When retorting oil shale, a delineated collection chamber near the top of the kiln collects gas and entrained oil mist rising through the kiln.

  5. Bacterial Physiological Diversity in the Rhizosphere of Range Plants in Response to Retorted Shale Stress

    PubMed Central

    Metzger, W. C.; Klein, D. A.; Redente, E. F.

    1986-01-01

    Bacterial populations were isolated from the soil-root interface and root-free regions of Agropyron smithii Rydb. and Atriplex canescens (Pursh) Nutt. grown in soil, retorted shale, or soil over shale. Bacteria isolated from retorted shale exhibited a wider range of tolerance to alkalinity and salinity and decreased growth on amino acid substrates compared with bacteria from soil and soil-over-shale environments. Exoenzyme production was only slightly affected by growth medium treatment. Viable bacterial populations were higher in the rhizosphere and rhizoplane of plants grown in retorted shale than in plants grown in soil or soil over shale. In addition, a greater number of physiological groups of rhizosphere bacteria was observed in retorted shale compared with soil alone. Two patterns of community similarity were observed in comparisons of bacteria from soil over shale with those from soil and retorted-shale environments. Root-associated populations from soil over shale had a higher proportion of physiological groups in common with those from the soil control than with those from the retorted-shale treatment. However, in non-rhizosphere populations, bacterial groups from soil over shale more closely resembled the physiological groups from retorted shale. PMID:16347169

  6. Oil shale retort apparatus

    SciTech Connect

    Reeves, A.A.; Mast, E.L.; Greaves, M.J.

    1990-08-14

    A retorting apparatus is described including a vertical kiln and a plurality of tubes for delivering rock to the top of the kiln and removal of processed rock from the bottom of the kiln so that the rock descends through the kiln as a moving bed. Distributors are provided for delivering gas to the kiln to effect heating of the rock and to disturb the rock particles during their descent. The distributors are constructed and disposed to deliver gas uniformly to the kiln and to withstand and overcome adverse conditions resulting from heat and from the descending rock. The rock delivery tubes are geometrically sized, spaced and positioned so as to deliver the shale uniformly into the kiln and form symmetrically disposed generally vertical paths, or rock chimneys'', through the descending shale which offer least resistance to upward flow of gas. When retorting oil shale, a delineated collection chamber near the top of the kiln collects gas and entrained oil mist rising through the kiln. 29 figs.

  7. Apparatus for oil shale retorting

    DOEpatents

    Lewis, Arthur E.; Braun, Robert L.; Mallon, Richard G.; Walton, Otis R.

    1986-01-01

    A cascading bed retorting process and apparatus in which cold raw crushed shale enters at the middle of a retort column into a mixer stage where it is rapidly mixed with hot recycled shale and thereby heated to pyrolysis temperature. The heated mixture then passes through a pyrolyzer stage where it resides for a sufficient time for complete pyrolysis to occur. The spent shale from the pyrolyzer is recirculated through a burner stage where the residual char is burned to heat the shale which then enters the mixer stage.

  8. Process for oil shale retorting

    DOEpatents

    Jones, John B.; Kunchal, S. Kumar

    1981-10-27

    Particulate oil shale is subjected to a pyrolysis with a hot, non-oxygenous gas in a pyrolysis vessel, with the products of the pyrolysis of the shale contained kerogen being withdrawn as an entrained mist of shale oil droplets in a gas for a separation of the liquid from the gas. Hot retorted shale withdrawn from the pyrolysis vessel is treated in a separate container with an oxygenous gas so as to provide combustion of residual carbon retained on the shale, producing a high temperature gas for the production of some steam and for heating the non-oxygenous gas used in the oil shale retorting process in the first vessel. The net energy recovery includes essentially complete recovery of the organic hydrocarbon material in the oil shale as a liquid shale oil, a high BTU gas, and high temperature steam.

  9. Water mist injection in oil shale retorting

    DOEpatents

    Galloway, T.R.; Lyczkowski, R.W.; Burnham, A.K.

    1980-07-30

    Water mist is utilized to control the maximum temperature in an oil shale retort during processing. A mist of water droplets is generated and entrained in the combustion supporting gas flowing into the retort in order to distribute the liquid water droplets throughout the retort. The water droplets are vaporized in the retort in order to provide an efficient coolant for temperature control.

  10. Method for retorting oil shale

    DOEpatents

    Shang, Jer-Yu; Lui, A.P.

    1985-08-16

    The recovery of oil from oil shale is provided in a fluidized bed by using a fluidizing medium of a binary mixture of carbon dioxide and 5 steam. The mixture with a steam concentration in the range of about 20 to 75 volume percent steam provides an increase in oil yield over that achievable by using a fluidizing gas of carbon dioxide or steam alone when the mixture contains higher steam concentrations. The operating parameters for the fluidized bed retorted are essentially the same as those utilized with other gaseous fluidizing mediums with the significant gain being in the oil yield recovered which is attributable solely to the use of the binary mixture of carbon dioxide and steam. 2 figs.

  11. Cyclone oil shale retorting concept. [Use it all retorting process

    SciTech Connect

    Harak, A.E.; Little, W.E.; Faulders, C.R.

    1984-04-01

    A new concept for above-ground retorting of oil shale was disclosed by A.E. Harak in US Patent No. 4,340,463, dated July 20, 1982, and assigned to the US Department of Energy. This patent titled System for Utilizing Oil Shale Fines, describes a process wherein oil shale fines of one-half inch diameter and less are pyrolyzed in an entrained-flow reactor using hot gas from a cyclone combustor. Spent shale and supplemental fuel are burned at slagging conditions in this combustor. Because of fines utilization, the designation Use It All Retorting Process (UIARP) has been adopted. A preliminary process engineering design of the UIARP, analytical tests on six samples of raw oil shale, and a preliminary technical and economic evaluation of the process were performed. The results of these investigations are summarized in this report. The patent description is included. It was concluded that such changes as deleting air preheating in the slag quench and replacing the condenser with a quench-oil scrubber are recognized as being essential. The addition of an entrained flow raw shale preheater ahead of the cyclone retort is probably required, but final acceptance is felt to be contingent on some verification that adequate reaction time cannot be obtained with only the cyclone, or possibly some other twin-cyclone configuration. Sufficient raw shale preheating could probably be done more simply in another manner, perhaps in a screw conveyor shale transporting system. Results of the technical and economic evaluations of Jacobs Engineering indicate that further investigation of the UIARP is definitely worthwhile. The projected capital and operating costs are competitive with costs of other processes as long as electric power generation and sales are part of the processing facility.

  12. Combuston method of oil shale retorting

    DOEpatents

    Jones, Jr., John B.; Reeves, Adam A.

    1977-08-16

    A gravity flow, vertical bed of crushed oil shale having a two level injection of air and a three level injection of non-oxygenous gas and an internal combustion of at least residual carbon on the retorted shale. The injection of air and gas is carefully controlled in relation to the mass flow rate of the shale to control the temperature of pyrolysis zone, producing a maximum conversion of the organic content of the shale to a liquid shale oil. The parameters of the operation provides an economical and highly efficient shale oil production.

  13. Oil shale retorting and combustion system

    DOEpatents

    Pitrolo, Augustine A.; Mei, Joseph S.; Shang, Jerry Y.

    1983-01-01

    The present invention is directed to the extraction of energy values from l shale containing considerable concentrations of calcium carbonate in an efficient manner. The volatiles are separated from the oil shale in a retorting zone of a fluidized bed where the temperature and the concentration of oxygen are maintained at sufficiently low levels so that the volatiles are extracted from the oil shale with minimal combustion of the volatiles and with minimal calcination of the calcium carbonate. These gaseous volatiles and the calcium carbonate flow from the retorting zone into a freeboard combustion zone where the volatiles are burned in the presence of excess air. In this zone the calcination of the calcium carbonate occurs but at the expense of less BTU's than would be required by the calcination reaction in the event both the retorting and combustion steps took place simultaneously. The heat values in the products of combustion are satisfactorily recovered in a suitable heat exchange system.

  14. Stabilizing in situ oil shale retorts with injected grout

    NASA Astrophysics Data System (ADS)

    1980-03-01

    A retort grouting process has been developed which would solve certain problems associated with in situ recovery of crude oil by retorting oil shale, such as surface subsidence, disturbance of groundwater flow, and accumulation of spent shale at the surface. Essentially, the process consists of using the spent shale to make a grout that can be injected into the retort after processing is completed. Bench-scale experiments using a high-temperature process show that grout can be prepared with sufficient strength, mobility, and permeability to stabilize processed in situ oil shale retorts. By reducing the need for surface disposal of spent shale and by increasing the quantity of shale that can be retorted in a given area, the grouting method should significantly improve the economics of the oil recovery process while also offering environmental advantages over surface processing of the shale.

  15. Effect of oil shale type and retorting atmosphere on the products from retorting various oil shales by the controlled-state retort

    SciTech Connect

    Duvall, J.J.; Mason, K.K.

    1980-02-01

    Six oil shales from different locations (the Green River formation of Colorado and Utah, the Antrim Basin of Michigan, and Morocco) having different Fischer Assay oil yields were retorted using three retorting atmospheres (N/sub 2/, N/sub 2//steam, and N/sub 2//steam/O/sub 2/) under the same retorting conditions. The products (oils, gases, waters, and shales) were analyzed and the data are reported. Changing retorting atmospheres had little observable effect on the product oils; however, there was a great deal of change in the composition and amount of gas produced. Steam in the retorting atmosphere increased the amount of carbon dioxide produced and decreased the amount of carbonate and organic carbon in the retorted shale. Addition of oxygen to N/sub 2//steam and increasing the maximum temperature compounded the above effect. 3 figures, 20 tables.

  16. Selected trace elements in plants grown on retorted oil shales

    SciTech Connect

    Kilkelly, M.K.; Lindsay, W.L.

    1982-07-01

    Western wheatgrass (Agropyron smithii Rybd. 'Arriba') and fourwing saltbush (Atriplex canescens (Pursh) Nutt.) were sampled from oil shale revegetation plots in northwestern Colorado. Plants were growing on two types of retorted shales: TOSCO II, produced by the Tosco Corporation; and USBM, produced by the U.S. Bureau of Mines. Various treatments included leaching and different depths of soil covering over the retorted shales. Plant samples were analyzed for B, Mo, As, Se, and F on a dry-weight basis. Plant samples with elevated Mo concentrations were also analyzed for Cu. Boron in western wheatgrass from the TOSCO retorted shale ranged from 85 to 202 ppm, compared with ranges of 4 to 15 ppm B in plants from the soil control. Analysis of variance indicated significant differences in B content due to site, aspect, type of retorted shale, and amount of soil cover over retorted shale. The concentration of B in western wheatgrass growing on retorted shales, especially TOSCO retorted shale, could affect plant growth. Fourwing saltbush samples, growing on USBM retorted shales, contained levels of Mo averaging 28 ppm, and low-to-moderate Cu content (4.8-6.8 ppm). This combination could make this species unacceptable as forage for ruminants. The concentrations of As (0.03-0.44 ppm), Se (0.02-0.94 ppm); and F (0.5-10.0 ppm) in the plant species investigated in this study were below limits usually set for either plant or animal toxicities and appear to be of little environmental significance.

  17. In-situ laser retorting of oil shale

    NASA Technical Reports Server (NTRS)

    Bloomfield, H. S. (Inventor)

    1977-01-01

    Oil shale formations are retorted in situ and gaseous hydrocarbon products are recovered by drilling two or more wells into an oil shale formation underneath the surface of the ground. A high energy laser beam is directed into the well and fractures the region of the shale formation. A compressed gas is forced into the well that supports combustion in the flame front ignited by the laser beam, thereby retorting the oil shale. Gaseous hydrocarbon products which permeate through the fractured region are recovered from one of the wells that were not exposed to the laser system.

  18. Microbial colonization of retorted shale in field and laboratory studies

    SciTech Connect

    Rogers, J.E.; McNair, V.M.; Li, S.W.; Garland, T.R.; Wildung, R.E.

    1982-08-01

    The microbial colonization of retorted shale was measured in field lysimeters and laboratory with retorted shale obtained from an above-ground retort operating in the direct heating mode. In field lysimeter studies, total aerobic heterotrophic bacterial colony forming units (cfu), as measured by a selective plating medium in surface horizons of retorted shale and adjacent soils, were similar (3.3 x 10/sup 6/ and 2.7 x 10/sup 6/ bacterial cfu/g dry weight) two months after disposal. However, unlike the soil that exhibited a diverse community, the retorted shale was dominated by a single Micrococcus species that composed 30% of the total bacterial community. After one and two years, the total aerobic heterotrophic bacterial cfu in the retorted shale and soil were again similar; however, no bacterium dominated either community. A core sample from the field lysimeter indicated microbial colonization to a depth of 150 cm after one year. An increased ratio of anaerobic to aerobic heterotrophic bacterial cfu in the deepest sample (120 to 150 cm) implied the development of anaerobic conditions. In the laboratory, aerobic heterotrophic bacteria were shown capable of using, as the sole source of carbon, retorted shale in liquid cultures. Of the added nutritional amendments, PO/sub 4//sup -3/, NO/sub 3//sup -/ and SO/sub 4//sup -2/, only phosphate markedly altered the colonization of retorted shale in liquid culture; shortening the lag phase of colonization from less than three to seven weeks to less than one week and leading to a greater aerobic heterotrophic population over the incubation interval. The addition of phosphate also led to a aerobic heterotrophic bacterial community composed entirely of Micrococcus species.

  19. Blasting technology for modified in-situ oil shale retorts

    SciTech Connect

    Ricketts, T.E.

    1982-09-01

    Occidental Oil Shale, Inc., an equal partner with Tenneco Shale Oil Company in the Cathedral Bluffs Shale Oil Company, has spent since 1972 developing and demonstrating its modified in situ oil shale process at its Logan Wash mine near Debeque, Colorado. The Occidental modified in situ process consists of first mining out a limited amount of rock from within an underground retort volume to allow the explosive expansion of the surrounding rock into the mined void volumes. The explosive expansion forms a large underground rubble bed contained within a retort chamber which must contain a fairly uniform particle size distribution and void redistribution to provide reasonable oil recovery during subsequent in situ processing operations. The processing involves first igniting the top of the rubble pile and then injecting air into the top of the retort to drive the combustion front downward through the entire rubblized volume. The oil is continuously collected at the bottom of the retort during the processing. Two side-by-side commercial-sized retorts, Retorts 7 and 8, have recently been constructed at the Logan Wash mine using newly developed horizontal free-face blasting technology. Retorts 7 and 8 were blasted in February and April of 1981, respectively, each using nearly 550,000 lbs. of explosives in ANFO equivalent loaded within nearly 550 blastholes for each retort. The resulting rubble beds were about 230-ft high with cross-sections of approximately 27,225 ft/sup 2/. The blasting principles used to construct these commercial-sized retorts and the rubblization results are described in detail in this paper.

  20. Model studies of ignition and return retort strategies for true in-situ retorting of Antrim oil shale

    SciTech Connect

    Crowl, D.A.; Piccirelli, R.A.

    1982-01-01

    The Sandia code describing the retorting of western oil shale through a horizontal crack was modified to describe the retorting of Michigan oil shale through a vertical crack. The resulting Wayne State University (WSU) modified Sandia code was subsequently utilized to examine the operation of a Michigan true in situ retort in the Antrim shale. The results demonstrated that this shale was able to support its own crack retort processes by partial gas phase combustion of the gas and oil products. Char combustion was found to be insignificant for all normal code runs. The WSU modified Sandia code was utilized to examine possible ignition and extraction strategies. 11 references.

  1. Characterization of in situ oil shale retorts prior to ignition

    DOEpatents

    Turner, Thomas F.; Moore, Dennis F.

    1984-01-01

    Method and system for characterizing a vertical modified in situ oil shale retort prior to ignition of the retort. The retort is formed by mining a void at the bottom of a proposed retort in an oil shale deposit. The deposit is then sequentially blasted into the void to form a plurality of layers of rubble. A plurality of units each including a tracer gas cannister are installed at the upper level of each rubble layer prior to blasting to form the next layer. Each of the units includes a receiver that is responsive to a coded electromagnetic (EM) signal to release gas from the associated cannister into the rubble. Coded EM signals are transmitted to the receivers to selectively release gas from the cannisters. The released gas flows through the retort to an outlet line connected to the floor of the retort. The time of arrival of the gas at a detector unit in the outlet line relative to the time of release of gas from the cannisters is monitored. This information enables the retort to be characterized prior to ignition.

  2. Methods for minimizing plastic flow of oil shale during in situ retorting

    DOEpatents

    Lewis, Arthur E.; Mallon, Richard G.

    1978-01-01

    In an in situ oil shale retorting process, plastic flow of hot rubblized oil shale is minimized by injecting carbon dioxide and water into spent shale above the retorting zone. These gases react chemically with the mineral constituents of the spent shale to form a cement-like material which binds the individual shale particles together and bonds the consolidated mass to the wall of the retort. This relieves the weight burden borne by the hot shale below the retorting zone and thereby minimizes plastic flow in the hot shale. At least a portion of the required carbon dioxide and water can be supplied by recycled product gases.

  3. Method for closing a drift between adjacent in situ oil shale retorts

    DOEpatents

    Hines, Alex E.

    1984-01-01

    A row of horizontally spaced-apart in situ oil shale retorts is formed in a subterranean formation containing oil shale. Each row of retorts is formed by excavating development drifts at different elevations through opposite side boundaries of a plurality of retorts in the row of retorts. Each retort is formed by explosively expanding formation toward one or more voids within the boundaries of the retort site to form a fragmented permeable mass of formation particles containing oil shale in each retort. Following formation of each retort, the retort development drifts on the advancing side of the retort are closed off by covering formation particles within the development drift with a layer of crushed oil shale particles having a particle size smaller than the average particle size of oil shale particles in the adjacent retort. In one embodiment, the crushed oil shale particles are pneumatically loaded into the development drift to pack the particles tightly all the way to the top of the drift and throughout the entire cross section of the drift. The closure between adjacent retorts provided by the finely divided oil shale provides sufficient resistance to gas flow through the development drift to effectively inhibit gas flow through the drift during subsequent retorting operations.

  4. Effects of retorting factors on combustion properties of shale char. 3. Distribution of residual organic matters.

    PubMed

    Han, Xiangxin; Jiang, Xiumin; Cui, Zhigang; Liu, Jianguo; Yan, Junwei

    2010-03-15

    Shale char, formed in retort furnaces of oil shale, is classified as a dangerous waste containing several toxic compounds. In order to retort oil shale to produce shale oil as well as treat shale char efficiently and in an environmentally friendly way, a novel kind of comprehensive utilization system was developed to use oil shale for shale oil production, electricity generation (shale char fired) and the extensive application of oil shale ash. For exploring the combustion properties of shale char further, in this paper organic matters within shale chars obtained under different retorting conditions were extracted and identified using a gas chromatography-mass spectrometry (GC-MS) method. Subsequently, the effects of retorting factors, including retorting temperature, residence time, particle size and heating rate, were analyzed in detail. As a result, a retorting condition with a retorting temperature of 460-490 degrees C, residence time of <40 min and a middle particle size was recommended for both keeping nitrogenous organic matters and aromatic hydrocarbons in shale char and improving the yield and quality of shale oil. In addition, shale char obtained under such retorting condition can also be treated efficiently using a circulating fluidized bed technology with fractional combustion. PMID:19896769

  5. Oil shale retorting - Measuring process yields

    SciTech Connect

    Atwood, M.T.; Tyson, S.W.

    1984-04-01

    For more than sixty years the rich oil shale formations of Colorado, Utah and Wyoming have been evaluated as a future source of petroleum. After many false starts, including the recent problems due to the economic conditions, the commercial production of shale oil will commence with the 1984 start-up of the Union Oil project near Parachute, Colorado. Other companies continue their interest and await only better economic conditions to become active again. This paper reviews some of the major elements involved in the production of shale oil with emphasis on means available to express the efficiency of production of pyrolysis liquids from oil shale rock.

  6. Ignition technique for an in situ oil shale retort

    DOEpatents

    Cha, Chang Y.

    1983-01-01

    A generally flat combustion zone is formed across the entire horizontal cross-section of a fragmented permeable mass of formation particles formed in an in situ oil shale retort. The flat combustion zone is formed by either sequentially igniting regions of the surface of the fragmented permeable mass at successively lower elevations or by igniting the entire surface of the fragmented permeable mass and controlling the rate of advance of various portions of the combustion zone.

  7. Fluid outlet at the bottom of an in situ oil shale retort

    DOEpatents

    Hutchins, Ned M.

    1984-01-01

    Formation is excavated from within the boundaries of a retort site in formation containing oil shale for forming at least one retort level void extending horizontally across the retort site, leaving at least one remaining zone of unfragmented formation within the retort site. A production level drift is excavated below the retort level void, leaving a lower zone of unfragmented formation between the retort level void and the production level drift. A plurality of raises are formed between the production level drift and the retort level void for providing product withdrawal passages distributed generally uniformly across the horizontal cross section of the retort level void. The product withdrawal passages are backfilled with a permeable mass of particles. Explosive placed within the remaining zone of unfragmented formation above the retort level void is detonated for explosively expanding formation within the retort site toward at least the retort level void for forming a fragmented permeable mass of formation particles containing oil shale within the boundaries of the retort site. During retorting operations products of retorting are conducted from the fragmented mass in the retort through the product withdrawal passages to the production level void. The products are withdrawn from the production level void.

  8. Raman/FTIR spectroscopy of oil shale retort gases

    SciTech Connect

    Richardson, J H; Monaco, S B; Sanborn, R H; Hirschfeld, T B; Taylor, J R

    1982-08-01

    A Raman facility was assembled in order to aid in the evaluation of the feasibility of using Raman or FTIR spectroscopy for analyzing gas mixtures of interest in oil shale. Applications considered in oil shale research included both retort monitoring and laboratory kinetic studies. Both techniques gave limits of detection between 10 and 1000 ppM for ten representative pertinent gases. Both techniques are inferior as a general analytical technique for oil shale gas analysis in comparison with mass spectroscopy, which had detection limits between 1 and 50 ppM for the same gases. The conclusion of the feasibility study was to recommend that mass spectroscopic techniques be used for analyzing gases of interest to oil shale.

  9. Method of design for vertical oil shale retorting vessels and retorting therewith

    DOEpatents

    Reeves, Adam A.

    1978-01-03

    A method of designing the gas flow parameters of a vertical shaft oil shale retorting vessel involves determining the proportion of gas introduced in the bottom of the vessel and into intermediate levels in the vessel to provide for lateral distribution of gas across the vessel cross section, providing mixing with the uprising gas, and determining the limiting velocity of the gas through each nozzle. The total quantity of gas necessary for oil shale treatment in the vessel may be determined and the proportion to be injected into each level is then determined based on the velocity relation of the orifice velocity and its feeder manifold gas velocity. A limitation is placed on the velocity of gas issuing from an orifice by the nature of the solid being treated, usually physical tests of gas velocity impinging the solid.

  10. Partitioning of major, minor, and trace elements during simulated in-situ oil shale retorting

    SciTech Connect

    Fox, J.P.

    1980-05-01

    The fate of inorganic constituents in Green River, Antrim, and Moroccan oil shales during in-situ retorting has been investigated. The partitioning or distribution of 50 elements to the spent shale, shale oil, retort water, and gases was studied by completing mass balances for several runs of three simulated in-situ retorts. Byproducts and products from 24 simulated in-situ retort runs were analyzed. The effect of shale origin and retort operating conditions, including temperature, particle size, atmosphere, and gas flow rate, on partitioning patterns was investigated, and the resulting data were used to develop a conceptual model of elemental partitioning during simulated in-situ retorting. Most of the 50 elements studied are not significantly mobilized during in-situ retorting. The only elements that are distributed in large quantities to the by-products are C, H, N, S, Cd, and Hg. Lesser but environmentally significant quatities of Se, As, Ni, and Co are distributed to the oils and waters, and at retorting temperatures in excess of about 900/sup 0/C, Se is mobilized to the gas phase. Mercury and Cd were the most mobile trace metals studied. About 70% of the Hg and 30% of the Cd were distributed to the gas phase. Mercury was released as a series of pulses in the last third of a retort run. Thermodynamic calculations indicated that elemental Hg is the major stable gas-phase species in all zones of an in-situ retort. The work demonstrated that elemental partitioning is controlled by the mineral residence of an element and the retort operating conditions employed. Significant differences were observed in the mobility and partitioning patterns of Green River, Antrim, and Moroccan oil shales. The only retorting conditions that had a statistically significant effect on partitioning patterns were temperature, input gas, particularly steam, and retort design and operation.

  11. Investigation of the geokinetics horizontal in situ oil shale retorting process. Quarterly report, October-December 1979

    SciTech Connect

    Hutchinson, D.L.

    1980-02-01

    The burn of Retort 17 was terminated December 10. Retort 18 was ignited November 12. Retort 17 produced 510 bbl during the quarter for the total of 3,775 bbl, while Retort 18 produced 1,187 bbl. The shale oil was analyzed. Environmental studies were done.

  12. Trace element partitioning during the retorting of Condor and Rundle oil shales

    SciTech Connect

    Patterson, J.H.; Dale, L.S.; Chapman, J.F. )

    1988-05-01

    Composite oil shale samples from the Condor and Rundle deposits in Queensland were retorted under Fischer assay conditions at temperatures ranging from 300 to 545{degree}C. Trace elements mobilized to the shale oil and retort water were determined at each temperature. The results were comparable for both oil shales. Several elements including arsenic, selenium, chlorine, bromine, cobalt, nickel, copper, and zinc were progressively mobilized as the retort temperature was increased. Most elements partition mainly to the oil and to a lesser extent to the retort water in a similar manner to other oil shales. For Rundle oil shales, trace element abundances in oils, and the proportions of elements mobilized, generally increased with oil shale grade. This was attributed to the reduced effect of adsorption and/or coking of heavier oil fractions during retorting of higher grade samples. Nickel porphyrins, unidentified organometallic compounds, pyrite, and halite are considered to be the sources of mobile trace elements. The results are relatively favorable for oil shale processing and show that arsenic is the most significant element in relation to both shale oil refining and disposal of retort waters.

  13. Method for rubblizing an oil shale deposit for in situ retorting

    DOEpatents

    Lewis, Arthur E.

    1977-01-01

    A method for rubblizing an oil shale deposit that has been formed in alternate horizontal layers of rich and lean shale, including the steps of driving a horizontal tunnel along the lower edge of a rich shale layer of the deposit, sublevel caving by fan drilling and blasting of both rich and lean overlying shale layers at the distal end of the tunnel to rubblize the layers, removing a substantial amount of the accessible rubblized rich shale to permit the overlying rubblized lean shale to drop to tunnel floor level to form a column of lean shale, performing additional sublevel caving of rich and lean shale towards the proximate end of the tunnel, removal of a substantial amount of the additionally rubblized rich shale to allow the overlying rubblized lean shale to drop to tunnel floor level to form another column of rubblized lean shale, similarly performing additional steps of sublevel caving and removal of rich rubble to form additional columns of lean shale rubble in the rich shale rubble in the tunnel, and driving additional horizontal tunnels in the deposit and similarly rubblizing the overlying layers of rich and lean shale and forming columns of rubblized lean shale in the rich, thereby forming an in situ oil shale retort having zones of lean shale that remain permeable to hot retorting fluids in the presence of high rubble pile pressures and high retorting temperatures.

  14. Preparation of grout for stabilization of abandoned in-situ oil shale retorts

    DOEpatents

    Mallon, Richard G.

    1982-01-01

    A process for the preparation of grout from burned shale by treating the burned shale in steam at approximately 700.degree. C. to maximize the production of the materials alite and larnite. Oil shale removed to the surface during the preparation of an in-situ retort is first retorted on the surface and then the carbon is burned off, leaving burned shale. The burned shale is treated in steam at approximately 700.degree. C. for about 70 minutes. The treated shale is then ground and mixed with water to produce a grout which is pumped into an abandoned, processed in-situ retort, flowing into the void spaces and then bonding up to form a rigid, solidified mass which prevents surface subsidence and leaching of the spent shale by ground water.

  15. Preparation of grout for stabilization of abandoned in-situ oil shale retorts. [Patent application

    DOEpatents

    Mallon, R.G.

    1979-12-07

    A process is described for the preparation of grout from burned shale by treating the burned shale in steam at approximately 700/sup 0/C to maximize the production of the materials alite and larnite. Oil shale removed to the surface during the preparation of an in-situ retort is first retorted on the surface and then the carbon is burned off, leaving burned shale. The burned shale is treated in steam at approximately 700/sup 0/C for about 70 minutes. The treated shale is then ground and mixed with water to produce a grout which is pumped into an abandoned, processed in-situ retort, flowing into the void spaces and then bonding up to form a rigid, solidified mass which prevents surface subsidence and leaching of the spent shale by ground water.

  16. EVALUATION OF THE EFFECTS OF WEATHERING ON A 50-YEAR OLD RETORTED OIL-SHALE WASTE PILE, RULISON EXPERIMENTAL RETORT, COLORADO.

    USGS Publications Warehouse

    Tuttle, Michele L.W.; Dean, Walter E.; Ackerman, Daniel J.; ,

    1985-01-01

    An oil-shale mine and experimental retort were operated near Rulison, Colorado by the U. S. Bureau of Mines from 1926 to 1929. Samples from seven drill cores from a retorted oil-shale waste pile were analyzed to determine 1) the chemical and mineral composition of the retorted oil shale and 2) variations in the composition that could be attributed to weathering. Unweathered, freshly-mined samples of oil shale from the Mahogany zone of the Green River Formation and slope wash collected away from the waste pile were also analyzed for comparison. The waste pile is composed of oil shale retorted under either low-temperature (400-500 degree C) or high-temperature (750 degree C) conditions. The results of the analyses show that the spent shale within the waste pile contains higher concentrations of most elements relative to unretorted oil shale.

  17. In situ oil shale retort with a generally T-shaped vertical cross section

    DOEpatents

    Ricketts, Thomas E.

    1981-01-01

    An in situ oil shale retort is formed in a subterranean formation containing oil shale. The retort contains a fragmented permeable mass of formation particles containing oil shale and has a production level drift in communication with a lower portion of the fragmented mass for withdrawing liquid and gaseous products of retorting during retorting of oil shale in the fragmented mass. The principal portion of the fragmented mass is spaced vertically above a lower production level portion having a generally T-shaped vertical cross section. The lower portion of the fragmented mass has a horizontal cross sectional area smaller than the horizontal cross sectional area of the upper principal portion of the fragmented mass above the production level.

  18. Effects of complexometric compounds found in liquid and solid oil shale waste products on release of chemical elements from retorted shale

    SciTech Connect

    Esmaili, E.; Carroll, R.B.; Jackson, L.P.

    1985-05-01

    Complexometric compounds found in oil shale wastes may have the ability to increase the release of trace elements from retorted oil shale when the solid and liquid wastes are codisposed. A laboratory investigation was conducted on the effects of various complexing agents found in liquid and solid oil shale wastes on the leachability of retorted shales. In batch experiments retorted shale samples were contacted with deionized-distilled water (DDW) and 10 different aqueous solutions of complexing agents. These agents included sodium-oxalate, ammonium-carbonate, sodium-thiosulfate, 2-pyridone, 2-hydroxy-6-methylpyridine, potassium-thiocyanate, acetonitrile, sodium-acetate, acetamide, and nicotinic acid. DDW leachate results were used as a baseline to compare with the results for aqueous complexometric leachates. Some of these agents aided in higher release of arsenic, boron, selenium, lead, and vanadium from the solids. The same complexing agents had different effects on different retorted shales, indicating that the results for one retorted shale may or may not be representative of other retorted shales. This is due to differences in mineralogical residence of elements in various retorted shales and differences in leachate chemical systems of various retorted shales. Concentration of cadium and cobalt did not exceed the quantitation limits of these elements in any of the leachates in this study. 10 refs., 15 tabs.

  19. Effect of retorted-oil shale leachate on a blue-green alga (Anabaena flos-aquae)

    SciTech Connect

    McKnight, D.M.; Pereira, W.E.; Rostad, C.E.; Stiles, E.A.

    1983-01-01

    Oil shale reserves in Piceance Creek and the White River, Colorado, contain retorted-shale piles which may pollute th eground water through leaching. Bioassay experiments were carried out to determine the effects of leachates on algae, particularly ANABAENA FLOSAQUAE and SCENEDESMUS. Tests were done to establish inhibitionary concentrations of the leachates from various sources of spent shale. Retorted-shale leachates had major effects on the algae papulations at a 40% concentration, minor effects at 8%, and no effects at 0.4%. Discrepancies between experimental results and actual retorted-shale piles are dixcussed. (JMT)

  20. Method for attenuating seismic shock from detonating explosive in an in situ oil shale retort

    DOEpatents

    Studebaker, Irving G.; Hefelfinger, Richard

    1980-01-01

    In situ oil shale retorts are formed in formation containing oil shale by excavating at least one void in each retort site. Explosive is placed in a remaining portion of unfragmented formation within each retort site adjacent such a void, and such explosive is detonated in a single round for explosively expanding formation within the retort site toward such a void for forming a fragmented permeable mass of formation particles containing oil shale in each retort. This produces a large explosion which generates seismic shock waves traveling outwardly from the blast site through the underground formation. Sensitive equipment which could be damaged by seismic shock traveling to it straight through unfragmented formation is shielded from such an explosion by placing such equipment in the shadow of a fragmented mass in an in situ retort formed prior to the explosion. The fragmented mass attenuates the velocity and magnitude of seismic shock waves traveling toward such sensitive equipment prior to the shock wave reaching the vicinity of such equipment.

  1. Solubility, mobility and plant uptake of toxic elements in retorted oil shales as affected by recarbonation

    SciTech Connect

    Reddy, K.J.

    1986-01-01

    The primary objective of this study was to develop a method of lowering the alkalinity of retorted shales and of reducing the solubility of toxic elements. The solubility relationships and mineral transformations associated with recarbonation of retorted shales were evaluated by determining the solubilities of different elements and by using X-ray diffraction analysis. An accurate method of measuring carbonate activity in shale extracts was developed. This method consisted of acidifying shale extracts with concentrated HCI. The evolved CO/sub 2/(g) was trapped in NaOH and titrated to pH 8.5. A computer speciation model was developed to calculate the equilibrium activities of different ions and the CO/sub 2/(g) partial pressure. Recarbonation dissolved silicates, restored the carbonate deficit, and lowered pH to near 8.5 when equilibrium with CaCO/sub 3/ and CO/sub 2/(g) partial pressure of approximately 10/sup -4.65/ atm. was attained. Furthermore, recarbonation decreased the solubilities of F, Ba, Cr, Sr, and Mo and lowered their concentrations in shale leachates, showing that recarbonation of spent shales can retard the movement of toxic elements into the groundwater. Tall wheatgrass (Agropyron elongatum) seeds placed in Lurgi shale without soil cover failed to germinate. On recarbonated Lurgi shale, plants grew normally without soil cover and accumulated normal levels of As, Se, Ba, B, Cu, Cd, Sr, and Ti. The results suggest that recarbonated retorted shales can be revegetated directly without a soil cover

  2. Method for forming an in situ oil shale retort with horizontal free faces

    DOEpatents

    Ricketts, Thomas E.; Fernandes, Robert J.

    1983-01-01

    A method for forming a fragmented permeable mass of formation particles in an in situ oil shale retort is provided. A horizontally extending void is excavated in unfragmented formation containing oil shale and a zone of unfragmented formation is left adjacent the void. An array of explosive charges is formed in the zone of unfragmented formation. The array of explosive charges comprises rows of central explosive charges surrounded by a band of outer explosive charges which are adjacent side boundaries of the retort being formed. The powder factor of each outer explosive charge is made about equal to the powder factor of each central explosive charge. The explosive charges are detonated for explosively expanding the zone of unfragmented formation toward the void for forming the fragmented permeable mass of formation particles having a reasonably uniformly distributed void fraction in the in situ oil shale retort.

  3. Investigation of the effects of heating rate on coking of shale during retorting

    SciTech Connect

    Guffey, F.D.; Hunter, D.E.

    1988-02-01

    The retorting of oil shale distributes organic carbon among three possible products: the liquid product, the noncondensible product, and the residual carbon (coke). The production of coke is detrimental because of the economic effects caused by the loss of organic carbon to this relatively intractable carbon form. Two reference oil shales, a Mahogany zone, Parachute Creek Member, Green River Formation oil shale from Colorado and a Clegg Creek Member, New Albany oil shale from Kentucky, were studied to evaluate the conditions that affect coke production during retorting. The variable that was studied in these experiments was the heating rate during retorting because heating rate has been indicated to have a direct effect on coke production (Burnham and Clarkson 1980). The six heating rates investigated covered the range from 1 to 650/degree/C/h (1.8 to 1169/degree/F/h). The data collected during these experiments were evaluated statistically in order to identify trends. The data for the eastern reference oil shale indicated a decrease in coke formation with increases in the heating rate. The liquid and noncondensible product yields both increased with increasing heating rate. The distribution of products in relation to retort heating rate follows the model suggested by Burnham and Clarkson (1980). Coke production during the retorting of western reference oil shale was found to be constant in relation to heating rate. The liquid product yield increased with increasing heating rate but the trend could not be verified at the 95% confidence level. The coke production observed in these experiments does not follow the prediction of the model. This may indicate that coke formation occurs early in the retorting process and may be limited by the availability of organic materials that form coke. 6 refs., 10 tabs.

  4. Investigation of the Geokinetics horizontal in situ oil-shale-retorting process. Fourth annual report, 1980

    SciTech Connect

    Hutchinson, D.L.

    1981-03-01

    The Geokinetics in situ shale oil project is a cooperative venture between Geokinetics Inc. and the US Department of Energy. The objective is to develop a true in situ process for recovering shale oil using a fire front moving in a horizontal direction. The project is being conducted at a field site, Kamp Kerogen, located 70 miles south of Vernal, Utah. This Fourth Annual Report covers work completed during the calendar year 1980. During 1980 one full-size retort was blasted. Two retorts, blasted the previous year, were burned. A total of 4891 barrels of oil was produced during the year.

  5. Investigation of the Geokinetics horizontal in situ oil shale retorting process. Quarterly report, January-March 1980

    SciTech Connect

    Hutchinson, D.L.

    1980-05-01

    Retort No. 18 produced 3479 barrels of oil during the quarter for a total of 4528 barrels to date. Chromatographic analyses of Retort No. 18 shale oil by the GKI analytical laboratory indicated variation in the oil from the wells near the air-in end and from the air-out end of the retort. Shale oil has been blended with Altamont crude (the Roosevelt refinery's normal feedstock); the distillation, API gravity, pour point, flash point, Naptha and Cat Gas were not affected by the shale oil. The diesel off the crude unit changed from water white to yellow, however, and a fine grayish-brown precipitate formed. Re-entry drilling was performed on Retorts No. 21, No. 22, and No. 23 during the quarter; tracer tests were run by Sandia Laboratories on Retorts No. 19, No. 21, No. 22, and No. 23. Blasthole drilling began on Retort No. 25.

  6. KECL finds that 18-8 alloys are needed for oil shale retorting

    SciTech Connect

    Not Available

    1987-03-01

    The Kentucky Energy Cabinet Laboratory (KECL) has, over a period of several years, investigated the corrosion and wear of materials of construction in oil shale retorting. The objective of the program was to develop an alloy performance database so that cost-effective materials of construction can be selected for plant designs. The KECL researchers conclude that 18-8 type alloys are needed for components exposed to gas and mist. For components exposed to interaction of erosion or abrasion with corrosion, wastage rates can be 10-20 times those under corrosion alone. These areas should probably be refractory or ceramic lined. Any metallic components (thermowells, etc.) will need to be protected by hard coatings or overlays. In condensate systems, the low alloys suffered extensive corrosive damage. Ferritic and stabilized austinitic stainless steels can be used to prevent stress corrosion cracking in these systems. 4 tables.

  7. Determination of polar organic solutes in oil-shale retort water

    USGS Publications Warehouse

    Leenheer, J.A.; Noyes, T.I.; Stuber, H.A.

    1982-01-01

    A variety of analytical methods were used to quantitatively determine polar organic solutes in process retort water and a gas-condensate retort water produced in a modified in situ oil-shale retort. Specific compounds accounting for 50% of the dissolved organic carbon were identified in both retort waters. In the process water, 42% of the dissolved organic carbon consisted of a homologous series of fatty acids from C2 to C10. Dissolved organic carbon percentages for other identified compound classes were as follows: aliphatic dicarboxylic acids, 1.4%; phenols, 2.2%; hydroxypyridines, 1.1%; aliphatic amides, 1.2%. In the gas-condensate retort water, aromatic amines were most abundant at 19.3% of the dissolved organic carbon, followed by phenols (17.8%), nitriles (4.3%), aliphatic alcohols (3.5%), aliphatic ketones (2.4%), and lactones (1.3%). Steam-volatile organic solutes were enriched in the gas-condensate retort water, whereas nonvolatile acids and polyfunctional neutral compounds were predominant organic constituents of the process retort water.

  8. Gas seal for an in situ oil shale retort and method of forming thermal barrier

    DOEpatents

    Burton, III, Robert S.

    1982-01-01

    A gas seal is provided in an access drift excavated in a subterranean formation containing oil shale. The access drift is adjacent an in situ oil shale retort and is in gas communication with the fragmented permeable mass of formation particles containing oil shale formed in the in situ oil shale retort. The mass of formation particles extends into the access drift, forming a rubble pile of formation particles having a face approximately at the angle of repose of fragmented formation. The gas seal includes a temperature barrier which includes a layer of heat insulating material disposed on the face of the rubble pile of formation particles and additionally includes a gas barrier. The gas barrier is a gas-tight bulkhead installed across the access drift at a location in the access drift spaced apart from the temperature barrier.

  9. INTEGRATION OF HIGH TEMPERATURE GAS REACTORS WITH IN SITU OIL SHALE RETORTING

    SciTech Connect

    Eric P. Robertson; Michael G. McKellar; Lee O. Nelson

    2011-05-01

    This paper evaluates the integration of a high-temperature gas-cooled reactor (HTGR) to an in situ oil shale retort operation producing 7950 m3/D (50,000 bbl/day). The large amount of heat required to pyrolyze the oil shale and produce oil would typically be provided by combustion of fossil fuels, but can also be delivered by an HTGR. Two cases were considered: a base case which includes no nuclear integration, and an HTGR-integrated case.

  10. Characterization of retorted oil shale and application to a model of leachate generation and transport

    SciTech Connect

    Ramirez, W.F.; Feerer, J.L.; Morelli, P.J.; Peterson, W.R.

    1985-01-01

    A characterization of the porous media properties of spent oil shale is presented. Mercury porosimetry, BET nitrogen adsorption, scanning electron microscopy, and x-ray fluorescence spectroscopy was performed on unconsolidated powders, consolidated chunks, and compacted powder pellets of oil shale retorted in the TOSCO, Paraho, and Lawrence Livermore experimental retorts. All results indicated that retorted oil shale has a unimodal pore size distribution. Mean pore sizes ranged from 5.0 microns for powders to 1.0 micron for compacted powder pellets to 0.5 microns for consolidated chunks. Surface area porosity, and permeability data are also presented. Dispersion and capacitance of leachate flowing through retorted TOSCO oil shale were measured using a sucrose tracer and a specially designed leaching column. Tracer breakout curves were best simulated using a three-parameter capacitance model which assumes leachate flow characterized by flowing fraction, dead space volume, and mass transfer between main channel flow and dead space volume. Two types of generation models were investigated in a mathematical simulation of the leaching experiment. These were an equilibrium model based on the Langmuir approach and a general power-law model based on surface concentration of a given leachate species. Equilibrium isotherms were generated using shaker experiments. Rate coefficients were approximated by a small differential column which was run at shorter residence times. Leachate concentrations were best simulated by the power-law model.

  11. Investigation of the geokinetics horizontal in situ oil shale retorting process. Quarterly report, April, May, June 1980

    SciTech Connect

    Hutchinson, D.L.

    1980-08-01

    The Retort No. 18 burn was terminated on May 11, 1980. A total of 5547 barrels of shale oil or 46 percent of in-place resource was recovered from the retort. The EPA-DOE/LETC post-burn core sampling program is underway on Retort No. 16. Eleven core holes (of 18 planned) have been completed to date. Preliminary results indicate excellent core recovery has been achieved. Recovery of 702 ft of core was accomplished. The Prevention of Significant Deterioration (PSD) permit application was submitted to the EPA regional office in Denver for review by EPA and Utah air quality officials. The application for an Underground Injection Control (UIC) permit to authorize GKI to inject retort wastewater into the Mesa Verde Formation is being processed by the State of Utah. A hearing before the Board of Oil, Gas and Mining is scheduled in Salt Lake City, Utah, for July 22, 1980. Re-entry drilling on Retort No. 24 is progressing and placement of surface equipment is underway. Retort No. 25 blasthole drilling was completed and blast preparations are ongoing. Retort No. 25 will be blasted on July 18, 1980. The retort will be similar to Retort No. 24, with improvements in blasthole loading and detonation. US Patent No. 4,205,610 was assigned to GKI for a shale oil recovery process. Rocky Mountain Energy Company (RME) is evaluating oil shale holdings in Wyoming for application of the GKI process there.

  12. Evaluation of physical-chemical and biological treatment of shale oil retort water

    SciTech Connect

    Mercer, B.W.; Mason, M.J.; Spencer, R.R.; Wong, A.L.; Wakamiya, W.

    1982-09-01

    Bench scale studies were conducted to evaluate conventional physical-chemical and biological treatment processes for removal of pollutants from retort water produced by in situ shale oil recovery methods. Prior to undertaking these studies, very little information had been reported on treatment of retort water. A treatment process train patterned after that generally used throughout the petroleum refining industry was envisioned for application to retort water. The treatment train would consist of processes for removing suspended matter, ammonia, biodegradable organics, and nonbiodegradable or refractory organics. The treatment processes evaluated include anaerobic digestion and activated sludge for removal of biodegradable organics and other oxidizable substances; activated carbon adsorption for removal of nonbiodegradable organics; steam stripping for ammonia removal; and chemical coagulation, sedimentation and filtration for removal of suspended matter. Preliminary cost estimates are provided.

  13. Water Usage for In-Situ Oil Shale Retorting – A Systems Dynamics Model

    SciTech Connect

    Earl D. Mattson; Larry Hull; Kara Cafferty

    2012-12-01

    A system dynamic model was construction to evaluate the water balance for in-situ oil shale conversion. The model is based on a systems dynamics approach and uses the Powersim Studio 9™ software package. Three phases of an insitu retort were consider; a construction phase primarily accounts for water needed for drilling and water produced during dewatering, an operation phase includes the production of water from the retorting process, and a remediation phase water to remove heat and solutes from the subsurface as well as return the ground surface to its natural state. Throughout these three phases, the water is consumed and produced. Consumption is account for through the drill process, dust control, returning the ground water to its initial level and make up water losses during the remedial flushing of the retort zone. Production of water is through the dewatering of the retort zone, and during chemical pyrolysis reaction of the kerogen conversion. The major water consumption was during the remediation of the insitu retorting zone.

  14. A plan for hydrologic investigations of in situ, oil-shale retorting near Rock Springs, Wyoming

    USGS Publications Warehouse

    Glover, Kent C.; Zimmerman, E.A.; Larson, L.R.; Wallace, J.C.

    1982-01-01

    The recovery of shale oil by the in-situ retort process may cause hydrologic impacts, the most significant being ground-water contamination and possible transport of contaminants into surrounding areas. Although these impacts are site-specific, many of the techniques used to investigate each retort operation commonly will be the same. The U.S. Geological Survey has begun a study of hydrologic impacts in the area of an in-situ retort near Rock Springs, Wyoming, as a means of refining and demonstrating these techniques. Geological investigations include determining the areal extent and thickness of aquifers. Emphasis will be placed on determining lithologic variations from geophysical logging. Hydrologic investigations include mapping of potentiometric surfaces, determining rates of ground-water discharge, and estimating aquifer properties by analytical techniques. Water-quality investigations include monitoring solute migration from the retort site and evaluating sampling techniques by standard statistical procedures. A ground-water-flow and solute-transport model will be developed to predict future movement of the water plume away from the retort. (USGS)

  15. Western oil-shale development: a technology assessment. Volume 4. Solid waste from mining and surface retorts

    SciTech Connect

    Not Available

    1982-01-01

    The overall objectives of this study were to: review and evaluate published information on the disposal, composition, and leachability of solid wastes produced by aboveground shale oil extraction processes; examine the relationship of development to surface and groundwater quality in the Piceance Creek basin of northwestern Colorado; and identify key areas of research necessary to quantitative assessment of impact. Information is presented under the following section headings: proposed surface retorting developments; surface retorting processes; environmental concerns; chemical/mineralogical composition of raw and retorted oil shale; disposal procedures; water quality; and research needs.

  16. Determining the locus of a processing zone in an in situ oil shale retort by sound monitoring

    DOEpatents

    Elkington, W. Brice

    1978-01-01

    The locus of a processing zone advancing through a fragmented permeable mass of particles in an in situ oil shale retort in a subterranean formation containing oil shale is determined by monitoring for sound produced in the retort, preferably by monitoring for sound at at least two locations in a plane substantially normal to the direction of advancement of the processing zone. Monitoring can be effected by placing a sound transducer in a well extending through the formation adjacent the retort and/or in the fragmented mass such as in a well extending into the fragmented mass.

  17. Method for explosive expansion toward horizontal free faces for forming an in situ oil shale retort

    DOEpatents

    Ricketts, Thomas E.

    1980-01-01

    Formation is excavated from within a retort site in formation containing oil shale for forming a plurality of vertically spaced apart voids extending horizontally across different levels of the retort site, leaving a separate zone of unfragmented formation between each pair of adjacent voids. Explosive is placed in each zone, and such explosive is detonated in a single round for forming an in situ retort containing a fragmented permeable mass of formation particles containing oil shale. The same amount of formation is explosively expanded upwardly and downwardly toward each void. A horizontal void excavated at a production level has a smaller horizontal cross-sectional area than a void excavated at a lower level of the retort site immediately above the production level void. Explosive in a first group of vertical blast holes is detonated for explosively expanding formation downwardly toward the lower void, and explosive in a second group of vertical blast holes is detonated in the same round for explosively expanding formation upwardly toward the lower void and downwardly toward the production level void for forming a generally T-shaped bottom of the fragmented mass.

  18. Process for oil shale retorting using gravity-driven solids flow and solid-solid heat exchange

    DOEpatents

    Lewis, Arthur E.; Braun, Robert L.; Mallon, Richard G.; Walton, Otis R.

    1986-01-01

    A cascading bed retorting process and apparatus in which cold raw crushed shale enters at the middle of a retort column into a mixer stage where it is rapidly mixed with hot recycled shale and thereby heated to pyrolysis temperature. The heated mixture then passes through a pyrolyzer stage where it resides for a sufficient time for complete pyrolysis to occur. The spent shale from the pyrolyzer is recirculated through a burner stage where the residual char is burned to heat the shale which then enters the mixer stage.

  19. Process for oil shale retorting using gravity-driven solids flow and solid-solid heat exchange

    DOEpatents

    Lewis, A.E.; Braun, R.L.; Mallon, R.G.; Walton, O.R.

    1983-09-21

    A cascading bed retorting process and apparatus are disclosed in which cold raw crushed shale enters at the middle of a retort column into a mixer stage where it is rapidly mixed with hot recycled shale and thereby heated to pyrolysis temperature. The heated mixture then passes through a pyrolyzer stage where it resides for a sufficient time for complete pyrolysis to occur. The spent shale from the pyrolyzer is recirculated through a burner stage where the residual char is burned to heat the shale which then enters the mixer stage.

  20. Acid mine drainage potential of raw, retorted, and combusted Eastern oil shale: Final report

    SciTech Connect

    Sullivan, P.J.; Yelton, J.L.; Reddy, K.J.

    1987-09-01

    In order to manage the oxidation of pyritic materials effectively, it is necessary to understand the chemistry of both the waste and its disposal environment. The objective of this two-year study was to characterize the acid production of Eastern oil shale waste products as a function of process conditions, waste properties, and disposal practice. Two Eastern oil shales were selected, a high pyrite shale (unweathered 4.6% pyrite) and a low pyrite shale (weathered 1.5% pyrite). Each shale was retorted and combusted to produce waste products representative of potential mining and energy conversion processes. By using the standard EPA leaching tests (TCLP), each waste was characterized by determining (1) mineralogy, (2) trace element residency, and (3) acid-base account. Characterizing the acid producing potential of each waste and potential trace element hazards was completed with laboratory weathering studies. 32 refs., 21 figs., 12 tabs.

  1. Method and apparatus for igniting an in situ oil shale retort

    DOEpatents

    Burton, Robert S.; Rundberg, Sten I.; Vaughn, James V.; Williams, Thomas P.; Benson, Gregory C.

    1981-01-01

    A technique is provided for igniting an in situ oil shale retort having an open void space over the top of a fragmented mass of particles in the retort. A conduit is extended into the void space through a hole in overlying unfragmented formation and has an open end above the top surface of the fragmented mass. A primary air pipe having an open end above the open end of the conduit and a liquid atomizing fuel nozzle in the primary air pipe above the open end of the primary air pipe are centered in the conduit. Fuel is introduced through the nozzle, primary air through the pipe, and secondary air is introduced through the conduit for vortical flow past the open end of the primary air pipe. The resultant fuel and air mixture is ignited for combustion within the conduit and the resultant heated ignition gas impinges on the fragmented mass for heating oil shale to an ignition temperature.

  2. Withdrawal of gases and liquids from an in situ oil shale retort

    DOEpatents

    Siegel, Martin M.

    1982-01-01

    An in situ oil shale retort is formed within a subterranean formation containing oil shale. The retort contains a fragmented permeable mass of formation particles containing oil shale. A production level drift extends below the fragmented mass, leaving a lower sill pillar of unfragmented formation between the production level drift and the fragmented mass. During retorting operations, liquid and gaseous products are recovered from a lower portion of the fragmented mass. A liquid outlet line extends from a lower portion of the fragmented mass through the lower sill pillar for conducting liquid products to a sump in the production level drift. Gaseous products are withdrawn from the fragmented mass through a plurality of gas outlet lines distributed across a horizontal cross-section of a lower portion of the fragmented mass. The gas outlet lines extend from the fragmented mass through the lower sill pillar and into the production level drift. The gas outlet lines are connected to a gas withdrawal manifold in the production level drift, and gaseous products are withdrawn from the manifold separately from withdrawal of liquid products from the sump in the production level drift.

  3. Documentation of INL’s In Situ Oil Shale Retorting Water Usage System Dynamics Model

    SciTech Connect

    Earl D Mattson; Larry Hull

    2012-12-01

    A system dynamic model was construction to evaluate the water balance for in-situ oil shale conversion. The model is based on a systems dynamics approach and uses the Powersim Studio 9™ software package. Three phases of an in situ retort were consider; a construction phase primarily accounts for water needed for drilling and water produced during dewatering, an operation phase includes the production of water from the retorting process, and a remediation phase water to remove heat and solutes from the subsurface as well as return the ground surface to its natural state. Throughout these three phases, the water is consumed and produced. Consumption is account for through the drill process, dust control, returning the ground water to its initial level and make up water losses during the remedial flushing of the retort zone. Production of water is through the dewatering of the retort zone, and during chemical pyrolysis reaction of the kerogen conversion. The document discusses each of the three phases used in the model.

  4. The sorptive behavior of organic compounds on retorted oil shale

    SciTech Connect

    Godrej, A.N.

    1989-01-01

    Single- and multisolute batch sorption isotherm experiments performed on Antrim spent shale from Michigan indicated a consistent behavior by the shale with respect to the four sorbates used-Phenol, 2-Hydroxynaphthalen (HN), 2,3,5-Trimethylphenol (TP) and 1,2,3,4-Tetrahydroquinoline (THQ). The sorptive capacity of the shale was least for Phenol and greatest for THQ, with order being Phenol < TP < HN < THQ. Single-solute continuous-flow column experiments on shale could not be better analyzed because of a lack of kinetic data. The order in which the compounds would reach a 50% breakthrough, and the sorptive amount order in batch multicomponent experiments, could be predicted from the single-solute batch data. The order at 10% breakthrough in the column experiments could not be predicted clearly. Averages of the ratios of the amount sorbed of any one component to the total sorbed amount of all components in multisolute systems were calculated and indicated the partitioning of the components as 11% Phenol, 32% HN, 37% THQ, and 20% TP in a tetrasolute system. Average ratios for bi- and trisolute systems computed from the tetrasolute system agreed to <11% for those compounds that srobed to larger extents (HN, THQ) and to <19% for those that sorbed to a smaller degree (Phenol, TP). A comparison with single-component batch isotherm experiments performed on Filtrasorb 300 granular activated carbon (GAC) showed that the shale had a sorptive capacity of about two orders of magnitude less than that of the GAC. The multicomponent shale data could not be adequately modelled with any one of three models - multicomponent Freundlich type and Langmuir models, and the simplified ideal adsorbed solution theory model.

  5. Investigation of the Geokinetics horizontal in situ oil shale retorting process. Quarterly report, July, August, September 1980

    SciTech Connect

    Hutchinson, D.L.

    1980-11-01

    Progress is reported by Geokinetics on the successful blasting of Retort No. 25. Preparations are described for the ignition of Retort No. 24 nearing completion. This will be the largest retort processing facility utilized to date. Meteorological data of the area was obtained for permit applications from the Utah Air Conservation Committee and the US EPA. These must be obtained before ignition of retort No. 24. Drilling for the post-burn core sampling program (Retorts No. 16 and No. 17) was completed during the quarter. Approval to inject effluent water into the Mesa Verde Formation through a deep well was obtained. Construction of a new 1 1/2 acre evaporating pond has begun. The DOE Oil Shale Task Force will aid in the environmental research program; its role is described. A new vibro-rotary hammer was tested. Drilling penetration rates increased by 35%. A patent on horizontal fracturing methods was obtained. (DMC)

  6. Determination of direct-acting mutagens and clastogens in oil shale retort process water

    SciTech Connect

    Chen, D.J.; Okinaka, R.T.; Strniste, G.F.; Meyne, J.

    1982-01-01

    Shale oil products contain various metabolically active and photoactive genotoxic components. In addition, preliminary observations indicated that retort process water contain direct-acting mutagens which cause significant increases in 6-thioguanine resistance (6TG/sup R/) mutants in Chinese hamster ovary (CHO) cells. However, we have been unable to demonstrate the occurrence of direct-acting mutagens in these process waters when tested in the standard Ames/Salmonella assay. In this report results are presented concerning the dose response of direct-acting mutagenicity in an above ground retort process (ARP) water and various fractions from it. Since many mutagenic agents are also clastogrenic, the cytogenetic and mutagenic effects of this process water under the same experimental conditions are compared.

  7. Unsaturated flow modeling of a retorted oil shale pile.

    SciTech Connect

    Bond, F.W.; Freshley, M.D.; Gee, G.W.

    1982-10-01

    The objective of this study was to demonstrate the capabilities of the UNSAT1D model for assessing this potential threat to the environment by understanding water movement through spent shale piles. Infiltration, redistribution, and drainage of water in a spent shale pile were simulated with the UNSAT1D model for two test cases: (1) an existing 35 m pile; and (2) a transient pile growing at a rate of 10 m/year for 5 years. The first test case simulated three different layering scenarios with each one being run for 1 year. The second test case simulated two different initial moisture contents in the pile with each simulation being run for 30 years. Grand Junction and Rifle, Colorado climatological data were used to provide precipitation and potential evapotranspiration for a wet (1979) and dry (1976) year, respectively. Hydraulic properties obtained from the literature on Paraho process spent shale soil, and clay were used as model input parameters to describe water retention and hydraulic conductivity characteristics. Plant water uptake was not simulated in either test case. The two test cases only consider the evaporation component of evapotranspiration, thereby maximizing the amount of water infiltrating into the pile. The results of the two test cases demonstrated that the UNSAT1D model can adequately simulate flow in a spent shale pile for a variety of initial and boundary conditions, hydraulic properties, and pile configurations. The test cases provided a preliminary sensitivity analysis in which it was shown that the material hydraulic properties, material layering, and initial moisture content are the principal parameters influencing drainage from the base of a pile. 34 figures, 4 tables.

  8. Leachate migration from an in situ oil-shale retort near Rock Springs, Wyoming

    USGS Publications Warehouse

    Glover, K.C.

    1986-01-01

    Geohydrologic factors influencing leachate movement from an in situ oil shale retort near Rock Springs, Wyoming, were investigated by developing models of groundwater flow and solute transport. Leachate, indicated by the conservative ion thiocyanate, has been observed 1/2 mi downgradient from the retort. The contaminated aquifer is part of the Green River Formation and consists of thin, permeable layers of tuff and sandstone interbedded with oil shale. Most solute migration has occurred in an 8-ft sandstone at the top of the aquifer. Groundwater flow in the study area is complexly 3-D and is characterized by large vertical variations in hydraulic head. The solute transport model was used to predict the concentration of thiocyanate at a point where groundwater discharges to the land surface. Leachates with peak concentrations of thiocyanate--45 mg/L or approximately one-half the initial concentration of retort water--were estimated to reach the discharge area during January 1985. Advantages as well as the problems of site specific studies are described. Data such as the distribution of thin permeable beds or fractures may introduce an unmanageable degree of complexity to basin-wide studies but can be incorporated readily in site specific models. Solute migration in the study area primarily occurs in thin permeable beds rather than in oil shale strata. Because of this behavior, leachate traveled far greater distances than might otherwise have been expected. The detail possible in site specific models permits more accurate prediction of solute transport than is possible with basin-wide models. A major problem in site specific studies is identifying model boundaries that permit the accurate estimation of aquifer properties. If the quantity of water flowing through a study area cannot be determined prior to modeling, the hydraulic conductivity and groundwater velocity will be estimated poorly. (Author 's abstract)

  9. Leachate migration from an in-situ oil-shale retort near Rock Springs, Wyoming

    USGS Publications Warehouse

    Glover, Kent C.

    1988-01-01

    Hydrogeologic factors influencing leachate movement from an in-situ oil-shale retort near Rock Springs, Wyoming, were investigated through models of ground-water flow and solute transport. Leachate, indicated by the conservative ion thiocyanate, has been observed ? mile downgradient from the retort. The contaminated aquifer is part of the Green River Formation and consists of thin, permeable layers of tuff and sandstone interbedded with oil shale. Most solute migration has occurred in an 8-foot sandstone at the top of the aquifer. Ground-water flow in the study area is complexly three dimensional and is characterized by large vertical variations in hydraulic head. The solute-transport model was used to predict the concentration of thiocyanate at a point where ground water discharges to the land surface. Leachate with peak concentrations of thiocyanate--45 milligrams per liter or approximately one-half the initial concentration of retort water--was estimated to reach the discharge area during January 1985. This report describes many of th3 advantages, as well as the problems, of site-specific studies. Data such as the distribution of thin, permeable beds or fractures might introduce an unmanageable degree of complexity to basin-wide studies but can be incorporated readily into site-specific models. Solute migration in the study area occurs primarily in thin, permeable beds rather than in oil-shale strata. Because of this behavior, leachate traveled far greater distances than might otherwise have been expected. The detail possible in site-specific models permits more accurate prediction of solute transport than is possible with basin-wide models. A major problem in site-specific studies is identifying model boundaries that permit the accurate estimation of aquifer properties. If the quantity of water flowing through a study area cannot be determined prior to modeling, the hydraulic conductivity and ground-water velocity will be poorly estimated.

  10. Fluidized-bed retorting of Colorado oil shale: Topical report. [None

    SciTech Connect

    Albulescu, P.; Mazzella, G.

    1987-06-01

    In support of the research program in converting oil shale into useful forms of energy, the US Department of Energy is developing systems models of oil shale processing plants. These models will be used to project the most attractive combination of process alternatives and identify future direction for R and D efforts. With the objective of providing technical and economic input for such systems models, Foster Wheeler was contracted to develop conceptual designs and cost estimates for commercial scale processing plants to produce syncrude from oil shales via various routes. This topical report summarizes the conceptual design of an integrated oil shale processing plant based on fluidized bed retorting of Colorado oil shale. The plant has a nominal capacity of 50,000 barrels per operating day of syncrude product, derived from oil shale feed having a Fischer Assay of 30 gallons per ton. The scope of the plant encompasses a grassroots facility which receives run of the mine oil shale, delivers product oil to storage, and disposes of the processed spent shale. In addition to oil shale feed, the battery limits input includes raw water, electric power, and natural gas to support plant operations. Design of the individual processing units was based on non-confidential information derived from published literature sources and supplemented by input from selected process licensors. The integrated plant design is described in terms of the individual process units and plant support systems. The estimated total plant investment is similarly detailed by plant section and an estimate of the annual operating requirements and costs is provided. In addition, the process design assumptions and uncertainties are documented and recommendations for process alternatives, which could improve the overall plant economics, are discussed.

  11. Studying the possibility of separate and joint combustion of Estonian shales and oil shale retort gas at thermal power plants

    NASA Astrophysics Data System (ADS)

    Roslyakov, P. V.; Attikas, Raivo; Zaichenko, M. N.; Pleshanov, K. A.; Ionkin, I. L.

    2015-10-01

    Results from investigations of joint and separate combustion of shale with a low heating value and oil shale retort gas (OSRG) are presented. The question about the possibility of further using shale as basic fuel is presently placed on the agenda. This matter is connected with the fact that the environmental regulations are imposing increasingly more stringent limits on emissions of harmful substances and that a decrease in the shale heating value is predicted. An adequate mathematical model of one of the TP-101 boilers installed at the Estonian power plant was developed and verified for carrying out investigations. Criteria for determining the reliability, efficiency, and environmental safety of equipment operation were formulated based on the operating chart, regulatory documents, and environmental requirements. Assessment of the possibility of boiler operation and the boiler unit as a whole in firing shale with a low calorific value has shown that despite fulfilling the required superheated steam parameters, quite a number of limitations relating to reliable operation of the boiler are not complied with. In addition, normal operation of forced-draft equipment and mills is possible only at low loads. For operation with joint combustion of shale and OSRG, the fractions of degraded-quality shale and OSRG (by heat) at which reliable and efficient operation of the boiler and boiler unit is ensured in the entire working range of loads with fulfilling the environmental standards are determined. Proposals on modifying the equipment for joint combustion of shale and OSRG are formulated. Boiler operation with firing OSRG as main fuel was modeled for three versions of furnace waterwall thermal efficiency with a view to estimate possible changes of boiler operation in carrying out waterwall cleaning operations. Calculation results have shown that operation of the boiler and boiler unit meeting the elaborated criteria is possible in the entire working range of loads with

  12. Post Retort, Pre Hydro-treat Upgrading of Shale Oil

    SciTech Connect

    Gordon, John

    2012-09-30

    Various oil feedstocks, including oil from oil shale, bitumen from tar sands, heavy oil, and refin- ery streams were reacted with the alkali metals lithium or sodium in the presence of hydrogen or methane at elevated temperature and pressure in a reactor. The products were liquids with sub- stantially reduced metals, sulfur and nitrogen content. The API gravity typically increased. Sodi- um was found to be more effective than lithium in effectiveness. The solids formed when sodium was utilized contained sodium sulfide which could be regenerated electrochemically back to so- dium and a sulfur product using a "Nasicon", sodium ion conducting membrane. In addition, the process was found to be effective reducing total acid number (TAN) to zero, dramatically reduc- ing the asphaltene content and vacuum residual fraction in the product liquid. The process has promise as a means of eliminating sulfur oxide and carbon monoxide emissions. The process al- so opens the possibility of eliminating the coking process from upgrading schemes and upgrad- ing without using hydrogen.

  13. Shale oil from the LLNL pilot retort: Metal ions as markers for water and dust

    SciTech Connect

    Coburn, T.T.; Duewer, T.I.; King, K.J.; Baldwin, D.E.; Cena, R.J.

    1993-12-31

    A metal ion found primarily in one of the three phases (oil, water, or dust) can serve as a marker for that phase. Emulsified water contains most of the magnesium detected in a shale oil. Extraction with saturated salt solution removes most of that Mg. The Mg content of retort water and the percentage of water in the oil (by ASTM D-4006) provides a good estimate of an oil`s Mg content. Mineral matter elements with poorly water soluble carbonates (or oxides) at pH 8 (calcium, for example) serve as markers for dust. When the water is separated from the main and light oil fractions before adding the heavy fraction containing dust, a much drier oil can be obtained. However, when done in this way, a powder containing Ca and Si remains in the oil; it cannot be completely removed even by filtering through a 0.24-{mu} frit. Iron, and certain other transition metal ions, is quite oil soluble. Extraction with dilute nitric acid to remove basic amines reduces the Fe content of shale oil. Unlike carboxylate- complexed metal ions in crude oils, the iron in shale oil does not extract efficiently into an aqueous EDTA solution (pH 5.9). Distillation of shale oil leaves most of the iron and other metals behind in the vacuum residum. Shale oil corrodes the hottest condenser`s steel interior; this is the chief source of iron in the oil.

  14. Apparatus and method for igniting an in situ oil shale retort

    DOEpatents

    Chambers, Carlon C.

    1981-01-01

    A method and apparatus for conducting such method are disclosed for igniting a fragmented permeable mass of formation particles in an in situ oil shale retort. The method is conducted by forming a hole through unfragmented formation to the fragmented mass. An oxygen-containing gas is introduced into the hole. A fuel is introduced into a portion of the hole spaced apart from the fragmented mass. The fuel and oxygen-containing gas mix forming a combustible mixture which is ignited for establishing a combustion zone in a portion of the hole spaced apart from the fragmented mass. The hot gas generated in the combustion zone is conducted from the hole into the fragmented mass for heating a portion of the fragmented mass above an ignition temperature of oil shale.

  15. Self-cementing properties of oil shale solid heat carrier retorting residue.

    PubMed

    Talviste, Peeter; Sedman, Annette; Mõtlep, Riho; Kirsimäe, Kalle

    2013-06-01

    Oil shale-type organic-rich sedimentary rocks can be pyrolysed to produce shale oil. The pyrolysis of oil shale using solid heat carrier (SHC) technology is accompanied by large amount of environmentally hazardous solid residue-black ash-which needs to be properly landfilled. Usage of oil shale is growing worldwide, and the employment of large SHC retorts increases the amount of black ash type of waste, but little is known about its physical and chemical properties. The objectives of this research were to study the composition and self-cementing properties of black ash by simulating different disposal strategies in order to find the most appropriate landfilling method. Three disposal methods were simulated in laboratory experiment: hydraulic disposal with and without grain size separation, and dry dumping of moist residue. Black ash exhibited good self-cementing properties with maximum compressive strength values of >6 MPa after 90 days. About 80% of strength was gained in 30 days. However, the coarse fraction (>125 µm) did not exhibit any cementation, thus the hydraulic disposal with grain size separation should be avoided. The study showed that self-cementing properties of black ash are governed by the hydration of secondary calcium silicates (e.g. belite), calcite and hydrocalumite.

  16. Gamma 60Co-irradiation of organic matter in the Phosphoria Retort Shale

    NASA Astrophysics Data System (ADS)

    Lewan, M. D.; Ulmishek, G. F.; Harrison, W.; Schreiner, F.

    1991-04-01

    Irradiation experiments were conducted on a thermally immature rock sample of the Phosphoria Retort Shale and its isolated kerogen. A 60Co-source for gamma radiation was employed at dosages ranging from 81 to 885 Mrads, which are attainable by Paleozoic and Precambrian black shales with syngenetic uranium enrichments. Kerogen elemental, isotopic, and pyrolysate compositions are not affected at these dosages, but the bitumens extracted from the irradiated rock are affected. The major effects are reductions in the amounts of bitumen, acyclic isoprenoids, and high-molecular weight acyclic carboxylic acids. Natural differences in the amounts of bitumen and acyclic isoprenoid due to regional and stratigraphie variations in organic source input and depositional conditions make the radiation-induced reductions in these parameters difficult to use as indicators of natural radiation damage in black shales. However, the preferential reduction in the high-molecular weight acyclic carboxylic acids, which are ubiquitous in the living precursory organic matter, is diagnostic of experimental γ-irradiation but may not be diagnostic of natural irradiation. The overall process associated with radiation damage is polymerization by cross-linking through a free radical mechanism. As a result, irradiation of organic matter in black shales is more likely to retard rather than enhance petroleum generation.

  17. Self-cementing properties of oil shale solid heat carrier retorting residue.

    PubMed

    Talviste, Peeter; Sedman, Annette; Mõtlep, Riho; Kirsimäe, Kalle

    2013-06-01

    Oil shale-type organic-rich sedimentary rocks can be pyrolysed to produce shale oil. The pyrolysis of oil shale using solid heat carrier (SHC) technology is accompanied by large amount of environmentally hazardous solid residue-black ash-which needs to be properly landfilled. Usage of oil shale is growing worldwide, and the employment of large SHC retorts increases the amount of black ash type of waste, but little is known about its physical and chemical properties. The objectives of this research were to study the composition and self-cementing properties of black ash by simulating different disposal strategies in order to find the most appropriate landfilling method. Three disposal methods were simulated in laboratory experiment: hydraulic disposal with and without grain size separation, and dry dumping of moist residue. Black ash exhibited good self-cementing properties with maximum compressive strength values of >6 MPa after 90 days. About 80% of strength was gained in 30 days. However, the coarse fraction (>125 µm) did not exhibit any cementation, thus the hydraulic disposal with grain size separation should be avoided. The study showed that self-cementing properties of black ash are governed by the hydration of secondary calcium silicates (e.g. belite), calcite and hydrocalumite. PMID:23528998

  18. A high liquid yield process for retorting various organic materials including oil shale

    DOEpatents

    Coburn, T.T.

    1988-07-26

    This invention is a continuous retorting process for various high molecular weight organic materials, including oil shale, that yields an enhanced output of liquid product. The organic material, mineral matter, and an acidic catalyst, that appreciably adsorbs alkenes on surface sites at prescribed temperatures, are mixed and introduced into a pyrolyzer. A circulating stream of olefin enriched pyrolysis gas is continuously swept through the organic material and catalyst, whereupon, as the result of pyrolysis, the enhanced liquid product output is provided. Mixed spent organic material, mineral matter, and cool catalyst are continuously withdrawn from the pyrolyzer. Combustion of the spent organic material and mineral matter serves to reheat the catalyst. Olefin depleted pyrolysis gas, from the pyrolyzer, is enriched in olefins and recycled into the pyrolyzer. The reheated acidic catalyst is separated from the mineral matter and again mixed with fresh organic material, to maintain the continuously cyclic process. 2 figs.

  19. High liquid yield process for retorting various organic materials including oil shale

    DOEpatents

    Coburn, Thomas T.

    1990-01-01

    This invention is a continuous retorting process for various high molecular weight organic materials, including oil shale, that yields an enhanced output of liquid product. The organic material, mineral matter, and an acidic catalyst, that appreciably adsorbs alkenes on surface sites at prescribed temperatures, are mixed and introduced into a pyrolyzer. A circulating stream of olefin enriched pyrolysis gas is continuously swept through the organic material and catalyst, whereupon, as the result of pyrolysis, the enhanced liquid product output is provided. Mixed spent organic material, mineral matter, and cool catalyst are continuously withdrawn from the pyrolyzer. Combustion of the spent organic material and mineral matter serves to reheat the catalyst. Olefin depleted pyrolysis gas, from the pyrolyzer, is enriched in olefins and recycled into the pyrolyzer. The reheated acidic catalyst is separated from the mineral matter and again mixed with fresh organic material, to maintain the continuously cyclic process.

  20. Shale worker's pneumoconiosis, associated respiratory ailments and skin tumors - plus ancillary documentation of mining and retorting processes and oil shale characterization (ex-shale workers in Scotland). Mid-project progress report

    SciTech Connect

    Seaton, A.

    1983-11-01

    Progress is reported on a study of survivors of Scottish oil shale mines, retorts, and refineries. The prevalence of pneumoconiosis and skin tumors is being determined by occupational histories, dermatology and smoking questionnaires, and x-ray surveys. A control study of workers of a colliery population in northeast England and mineralogical characterization of Scottish and Colorado shales are also being conducted. (ACR)

  1. A feasibility study of oil shale fired pulse combustors with applications to oil shale retorting

    SciTech Connect

    Morris, G.J.; Johnson, E.K.; Zhang, G.Q.; Roach, R.A.

    1992-07-01

    The results of the experimental investigation performed to determine the feasibility of using pulverized Colorado oil shale to fuel a bench scale pulse combustor reveal that oil shale cannot sustain pulsations when used alone as fuel. Trace amounts of propane mixed with the oil shale enabled the pulsations, however. Up to 80% of the organic material in the oil shale was consumed when it was mixed with propane in the combustor. Beyond the feasibility objectives, the operating conditions of the combustor fuel with propane and mixtures of oil shale and propane were characterized with respect to pulsation amplitude and frequency and the internal combustor wall temperature over fuel lean and fuel rich stoichiometries. Maximum pressure excursions of 12.5 kPa were experienced in the combustor. Pulsation frequencies ranged from 50 to nearly 80 Hz. Cycle resolved laser Doppler anemometry velocities were measured at the tail pipe exit plane. Injecting inert mineral matter (limestone) into the pulse combustor while using propane fuel had only a slight effect on the pulsation frequency for the feed rates tested.

  2. Explosively produced fracture of oil shale. Progress report, July-September 1981. [Field experiments; computer models; retort stability

    SciTech Connect

    1982-04-01

    The Los Alamos National Laboratory is conducting rock fragmentation research in oil shale to develop the blasting technologies and designs required to create a rubble bed for a modified in situ retort. This report outlines our first field experiments at the Anvil Points Mine in Colorado. These experiments are part of a research program, sponsored by the Laboratory through the Department of Energy and by a Consortium of oil companies. Also included are some typical numerical calculations made in support of proposed field experiments. Two papers detail our progress in computer modeling and theory. The first presents a method for eliminating hourglassing in two-dimensional finite-difference calculations of rock fracture without altering the physical results. The second discusses the significant effect of buoyancy on tracer gas flow through the retort. A paper on retort stability details a computer application of the Schmidt graphical method for calculating fine-scale temperature gradients in a retort wall. The final paper, which describes our approach to field experiments, presents the instrumentation and diagnostic techniques used in rock fragmentation experiments at Anvil Points Mine.

  3. Effects of stripped oil shale retort water on fishes, birds, and mammals

    SciTech Connect

    Nystrom, R.R.

    1983-01-01

    Golden hamsters (Mesocricetus auratus Water), coturnix quail (Coturnix coturnix Teminck and Schlegal), fathead minnows (Pimphales promelas Rafinesque), and rainbow trout (Salmo gairdneri Richardson) were subjected to various exposures of stripped oil shale retort water (SRW). Chronic low-level exposures of all experimental animals to SRW revealed no adverse histological effects attributable to SRW. Also, production and development of second generation fathead minnows and coturnix quail exposed to SRW was normal. Subacute exposure of rainbow trout to SRW produced ultrastructural changes detected by transmission, scanning, and freeze fracture electron microscopy) in the gill, liver, and kidney tissues. The gills showed a swelling of secondary lamellae, disorganization of normal tissue architecture, and sloughing of respiratory cells. The liver contained lamellar bodies not seen in the controls. Relatively large, electron dense, membrane-bounded deposits were present in proximal tubule cells of the kidney. Sodium arsenite (a significant component of SRW) was shown to cause swelling of granular endosplasmic reticulum in quail liver tissue with an acute exposure. This effect could be related to the fact that arsenic inhibits ATP production, which would decrease the ability of the sodium pumps to maintain a normal osmotic balance.

  4. Method for establishing a combustion zone in an in situ oil shale retort having a pocket at the top

    DOEpatents

    Cha, Chang Y.

    1980-01-01

    An in situ oil shale retort having a top boundary of unfragmented formation and containing a fragmented permeable mass has a pocket at the top, that is, an open space between a portion of the top of the fragmented mass and the top boundary of unfragmented formation. To establish a combustion zone across the fragmented mass, a combustion zone is established in a portion of the fragmented mass which is proximate to the top boundary. A retort inlet mixture comprising oxygen is introduced to the fragmented mass to propagate the combustion zone across an upper portion of the fragmented mass. Simultaneously, cool fluid is introduced to the pocket to prevent overheating and thermal sloughing of formation from the top boundary into the pocket.

  5. Irrigation experiments with produced waters from the retorting of oil shale

    SciTech Connect

    Hutchinson, D.L.

    1980-12-01

    The research described herein was conducted by Geokinetics to qualitatively assess the tolerance of native and certain introduced species of vegetation to irrigation with produced water from the retorting of oil shale. Two separate experiments were conducted at the Kamp Kerogen field site in Uintah County, Utah. The results indicate possible effects on vegetation that a prolonged exposure to produced water would have. The two simple experiments were initiated during the summer of 1979. It was expected that irrigation with produced water would eventually result in detrimental effects to the plants receiving it; the concentrations of boron, molybdenum, arsenic, oil and other constituents in untreated production waters are high enough to likely cause damage to plants. In one experiment a 27 foot by 27 foot plot of native vegetation was irrigated with one inch of produced water per week for five weeks using a lawn sprinkler. Grasses and shrubs within the test plot appeared to have died; germination of annual plants was greatly inhibited. In the other experiment, 30 container-grown seedlings ranging in height from 0.3 feet to 3.0 feet were transplanted. Six species of broadleaf, deciduous trees not native to the test site were represented by five seedlings each. All 30 trees received well water irrigation for one month, after which four trees of each species were irrigated with produced water for seven weeks. One tree of each species continued to receive well water throughout the experiment; only two of those trees survived the summer of 1979. All six species appeared to have been adversely affected by produced water. The horse chesnut trees were the hardiest of the species planted. Most of the 30 trees, including those irrigated with well water, did not survive the winter season.

  6. Pollution control technical manual for Unishale B and Unishale C oil-shale retorting. Final report, October 1985-October 1986

    SciTech Connect

    Gala, K.H.

    1986-12-01

    The report describes the Unishale B and C oil shale plants, characterizes the waste streams produced in each medium, and generally discusses the commercially available controls that can be applied to the plant waste streams. Several controls are examined in more detail for each medium to illustrate typical control technology operation. Control technology cost and performance estimates are presented, together with descriptions of the discharge streams, secondary waste streams, and energy requirements. Unishale B and C are two retorting technologies developed by UNOCAL (Union Oil Company of California). The engineering design, stream compositions, and pollution control alternatives presented do not represent or reproduce exactly those proposed or employed by UNOCAL at its Parachute facility or any other such facility. The design presented here represents one of many possible configurations for an oil shale facility based on Union's technology. Unishale B or C plants of the future can be expected to be similar to that described here.

  7. Laboratory study of the effects of combustion gases on retorting of Green River oil shale with superheated steam

    SciTech Connect

    Tyler, A.L.; Bullen, E.A.; Jacobs, H.R.

    1983-04-01

    The leached zone of the Parachute Creek member of the Piceance Basin in the Green River Formation has a unique natural porosity that makes it a likely source for in-situ production of oil from oil shale by injection of superheated steam. The Equity Oil Co. of Salt Lake City, in cooperation with the U. S. Department of Energy, carried out field tests using surface generated steam. Difficulties in delivering steam of sufficiently high temperature to the formation resulted in an experiment which was only marginally successful yielding less than 1 percent of the estimated 300,000 barrels of oil in place. In 1981, personnel at Sandia National Laboratory suggested that a downhole steam generator which could produce steam at temperatures in excess of 1000/sup 0/F (538/sup 0/C) at depth could well solve the temperature problem. In order to evaluate the effects of combustion gases which would be injected along with steam, should a downhole steam generator be used, laboratory studies have been completed using steam diluted with CO/sub 2/ and with CO/sub 2/ and N/sub 2/ as the heating medium. Results of experiments in an autoclave reactor and in a laboratory retort are reported. The temperature, residence time, and partial pressure of steam are the parameters which effect oil yield and oil quality. Oil properties are reported for several experimental conditions and include oil yield, boiling point distributions, pour points, gravity, and elemental and hydrocarbon-type analyses. Both the autoclave and laboratory retort experiments indicate that CO/sub 2/ and N/sub 2/ do not take a reactive part in the formation of oils except as they dilute the steam. However, the presence of CO/sub 2/ in the gaseous atmosphere during retorting does promote a low-temperature transformation of dolomite to calcite in the inorganic matrix of the oil shale.

  8. Potential biological hazards of nickel arsenides associated with retorting of oil shale: toxic effects of particulate Ni/sub 5/As/sub 2/

    SciTech Connect

    Gurley, L.R.; Tobey, R.A.; Valdez, J.G.; Halleck, M.S.; Barham, S.S.

    1981-11-01

    Considerations of (1) oil shale retort operating conditions, (2) oil shale elemental cmposition, (3) nickel and arsenic physicochemical properties, and (4) oil shale matrix structure lead to the suggestion that nickel arsenides may be formed during the oil shale retorting process. The biological effects of nickel arsenides have not been previously studied. However, crystal structure similarities between nickel subarsenide and the potent carcinogens nickel subsulfide and nickel subselenimide have caused concern that nickel arsenides may have adverse effects on biological systems. To determine if fugitive nickel arsenides from an oil shale retort could pose a threat to personnel in the workplace or to other living organisms in the environment, a program to study the toxicity of nickel arsenides has been initiated. Five stable nickel arsenides (Ni/sub 5/As/sub 2/, Ni/sub 2/As, Ni/sub 11/As/sub 8/, NiAs, and NiAs/sub 2/) and nickel arsenic sulfide (NiAsS) are considered possible species for consideration. This report describes some effects of particulate Ni/sub 5/As/sub 2/ on cultured mammalian cells.

  9. Effects of in-situ oil-shale retorting on water quality near Rock Springs, Wyoming, Volume 1

    SciTech Connect

    Lindner-Lunsford, J.B.; Eddy, C.A.; Plafcan, M.; Lowham, H.W.

    1990-12-01

    Experimental in-situ retorting techniques (methods of extracting shale oil without mining) were used from 1969 to 1979 by the Department of Energy's (DOE) Laramie Energy Technology Center (LETC) at a test area near Rock Springs in southwestern Wyoming. The retorting experiments at site 9 have produced elevated concentrations of some contaminants in the ground water. During 1988 and 1989, the US Geological Survey, in cooperation with the US Department of Energy, conducted a site characterization study to evaluate the chemical contamination of ground water at the site. Water samples from 34 wells were analyzed; more than 70 identifiable organic compounds were detected using a combination of gas chromatography and mass spectrometry analytical methods. This report provides information that can be used to evaluate possible remedial action for the site. Remediation techniques that may be applicable include those techniques based on removing the contaminants from the aquifer and those based on immobilizing the contaminants. Before a technique is selected, the risks associated with the remedial action (including the no-action alternative) need to be assessed, and the criteria to be used for decisions regarding aquifer restoration need to be defined. 31 refs., 23 figs., 9 tabs.

  10. Oxidation/gasification of carbon residue on retorted oil shale. Final report

    SciTech Connect

    Thomson, W. J.

    1984-01-16

    Studies of the oxidation and gasification of oil shale char were extended to an investigation of the effects of mineral catalysis. Six shales with differing mineral compositions were studied, including samples from the saline zone in the Western Colorado and from the Antrim shales of Michigan. Oxidation kinetics data, corrected for mass transfer effects, were compared for all six samples. A high assay shale from Utah and a sample from the saline zone were found to have the highest oxidation rates. By examining the data for shales which were water leached and thermally pretreated, it was concluded that both NaO and CaO act as oxidation catalysts. However, as a result of mineral decomposition experiments conducted with a sample from the C-a lease tract, it appears as though the ankeritic dolomite fraction will not decompose as long as there is a minimal CO/sub 2/ over pressure. Rather, low temperature silication reactions appear to take place once the temperature exceeds 925/sup 0/K. An extensive evaluation was also completed for the gasification of an Antrim shale from Michigan. Both the rates of CO/sub 2/ and steam gasification of the char were found to be markedly lower than that observed for a shale sample from the Parachute Creek member in Colorado. However, unlike the Colorado shale, the make gas resulting from the steam gasification of the Antrim shale produced nearly equal quantities of CO and CO/sub 2/. Thus, despite the high concentration of iron in the Antrim shale, the water gas shift reaction is not catalyzed nearly to the same extent as in western shales.

  11. Investigation of the geokinetics horizontal in situ oil shale retorting process. Quarterly report, July, August, September 1983

    SciTech Connect

    Henderson, K.B.

    1984-01-01

    Retort No. 27 was ignited using a new procedure and 47 days of operation were completed in the quarter. For retort No. 28 air injection and off gas piping and manifolding was completed along with the installation of electrical and instrumentation wiring. The off gas processing plant for the two retorts was completed and an initial shakedown run made.

  12. Laboratory modeling of in-situ retorting of oil shale by superheated-steam injection. BX in-situ oil shale project

    SciTech Connect

    Dougan, P.M.

    1981-08-03

    The laboratory study has shown that retorting of oil shale by a superheated steam is practical; yield of evolved product is given by 1-X = 1-e/sup Kt/, where K = -4.83 x 10/sup 14/e/sup -//sup 22,900/T/. Evolved oil has a high pour point 70 to 82/sup 0/F low API gravity approx. 21, but it is cracked in steam above 525/sup 0/F, resulting in in-situ recovered oil with low pour point below 30/sup 0/F. The Parachute Creek formation contains carbonates and bicarbonates which accounts for nearly all the CO/sub 2/ in the off-gases; thus no water-shift or water-gas reaction probably is taking place. The oils have lower molecular weight and larger fractions of naptha, light distillate and light gas oil than ordinary shale oils. The nitrogen, sulfur, and oxygen are lowered. The steam cracking leads to a less polar product. 48 figures. (DLC)

  13. Oil shale mining cost analysis. Volume I. Surface retorting process. Final report

    SciTech Connect

    Resnick, B.S.; English, L.M.; Metz, R.D.; Lewis, A.G.

    1981-01-01

    An Oil Shale Mining Economic Model (OSMEM) was developed and executed for mining scenarios representative of commercially feasible mining operations. Mining systems were evaluated for candidate sites in the Piceance Creek Basin. Mining methods selected included: (1) room-and-pillar; (2) chamber-and-pillar, with spent shale backfilling; (3) sublevel stopping; and (4) sublevel stopping, with spent shale backfilling. Mines were designed to extract oil shale resources to support a 50,000 barrels-per-day surface processing facility. Costs developed for each mining scenario included all capital and operating expenses associated with the underground mining methods. Parametric and sensitivity analyses were performed to determine the sensitivity of mining cost to changes in capital cost, operating cost, return on investment, and cost escalation.

  14. A feasibility study of oil shale fired pulse combustors with applications to oil shale retorting. Final report

    SciTech Connect

    Morris, G.J.; Johnson, E.K.; Zhang, G.Q.; Roach, R.A.

    1992-07-01

    The results of the experimental investigation performed to determine the feasibility of using pulverized Colorado oil shale to fuel a bench scale pulse combustor reveal that oil shale cannot sustain pulsations when used alone as fuel. Trace amounts of propane mixed with the oil shale enabled the pulsations, however. Up to 80% of the organic material in the oil shale was consumed when it was mixed with propane in the combustor. Beyond the feasibility objectives, the operating conditions of the combustor fuel with propane and mixtures of oil shale and propane were characterized with respect to pulsation amplitude and frequency and the internal combustor wall temperature over fuel lean and fuel rich stoichiometries. Maximum pressure excursions of 12.5 kPa were experienced in the combustor. Pulsation frequencies ranged from 50 to nearly 80 Hz. Cycle resolved laser Doppler anemometry velocities were measured at the tail pipe exit plane. Injecting inert mineral matter (limestone) into the pulse combustor while using propane fuel had only a slight effect on the pulsation frequency for the feed rates tested.

  15. Reaction rate kinetics for in situ combustion retorting of Michigan Antrim oil shale

    USGS Publications Warehouse

    Rostam-Abadi, M.; Mickelson, R.W.

    1984-01-01

    The intrinsic reaction rate kinetics for the pyrolysis of Michigan Antrim oil shale and the oxidation of the carbonaceous residue of this shale have been determined using a thermogravimetric analysis method. The kinetics of the pyrolysis reaction were evaluated from both isothermal and nonisothermal rate data. The reaction was found to be second-order with an activation energy of 252.2 kJ/mole, and with a frequency factor of 9.25 ?? 1015 sec-1. Pyrolysis kinetics were not affected by heating rates between 0.01 to 0.67??K/s. No evidence of any reactions among the oil shale mineral constituents was observed at temperatures below 1173??K. However, it was found that the presence of pyrite in oil shale reduces the primary devolatilization rate of kerogen and increases the amount of residual char in the spent shale. Carbonaceous residues which were prepared by heating the oil shale at a rate of 0.166??K/s to temperatures between 923??K and 1073??K, had the highest reactivities when oxidized at 0.166??K/s in a gas having 21 volume percent oxygen. Oxygen chemisorption was found to be the initial precursor to the oxidation process. The kinetics governing oxygen chemisorption is (Equation Presented) where X is the fractional coverage. The oxidation of the carbonaceous residue was found also to be second-order. The activation energy and the frequency factor determined from isothermal experiments were 147 kJ/mole and 9.18??107 sec-1 respectively, while the values of these parameters obtained from a nonisothermal experiment were 212 kJ/mole and 1.5??1013 sec-1. The variation in the rate constants is attributed to the fact that isothermal and nonisothermal analyses represent two different aspects of the combustion process.

  16. Investigation of the geokinetics horizontal in situ oil shale retorting process. Quarterly report, October, November, December 1983

    SciTech Connect

    Henderson, K.B.

    1984-03-01

    Retort No. 27 was ignited on August 11, 1983 and by December 31 had completed 139 days of operation and produced 11,420 barrels of oil. Retort No. 28 was ignited on October 18, 1983 and on December 31 had completed 74 days of operation and produced 5,285 barrels of oil. The off-gas processing plants for the two retorts was completed and put through a shakedown run. Concentration levels of H/sub 2/S and NH/sub 3/ in the retort off gas did not warrant plant operation in the fourth quarter. Environmental studies are reported.

  17. Plant response to aqueous effluents derived from in-situ fossil-fuel processing. Part I. Eight plant species and their response to Omega 9 oil-shale retort water. [Wildrye; wheatgrass; alkali sacaton; sandreed; pointvetch

    SciTech Connect

    Skinner, Q.D.

    1981-11-01

    Growth response to water collected from an in situ oil shale retort experiment was studied. The purposes were to: (1) evaluate effect of retort water on plants; (2) document effective parameters for detecting differences in plant growth by species. A self feeding hydroponic system was utilized to subject different dilutions of oil shale retort water to plants grown in horticulture grade perlite under greenhouse conditions for 10 weeks. Parameters measured included: (1) leaf area, (2) total dry weight, (3) shoot weight, (4) root weight, (5) root/shoot ratio, and (6) shoot/leaf area ratio. Seven grass and one forb species were utilized as test plants. Results showed growth to be impaired, species to respond differently to retort water, and parameters measured to vary as to their ability to detect change in growth response.

  18. Chemiluminescence vs. Kjeldahl determination of nitrogen in oil shale retort waters and organonitrogen compounds

    SciTech Connect

    Jones, B.M.; Daughton, C.G.

    1985-10-01

    The applicability of combustion/chemiluminescent nitrogen analysis to quantifying nitrogen in oil shale wastewaters and various representative chemical classes was demonstrated. Only azoxy compounds and those containing the pyrazole nucleus were not amenable to analysis. The majority of 56 compounds tested yielded from 90% to 110% of their theoretical nitrogen contents: enhanced recovery was found for nitrogen oxide salts. For 12 oil shale wastewaters, combustion/chemiluminescence gave total nitrogen values (1100-28800 mg/L) that did not differ statistically (P > 0.10) from those obtained by the time-consuming wet-chemical Kjeldahl method. The relative standard deviations for ten matrix or solvent effects were found. 28 references, 1 figure, 3 tables.

  19. Sublethal effects of an in situ oil shale retort water on rainbow trout. [Salmo gairdneri

    SciTech Connect

    Lebsack, M.E.; Anderson, A.D.; Nelson, K.F.; Farrier, D.S.

    1981-01-01

    An in situ oil shale process water (Omega-9 water) was used in sublethal concentrations in flow-through bioassay with rainbow trout (Salmo gairdneri). Exposure for 96 hr to 0.3% of Omega-9 water (approximately 70% of the LC50) decreased blood packed cell volume (PCV) and HB concentration. This concentration of Omega-9 water also decreased plasma alkaline phosphatase (AP) activity and protein concentration and caused 3-fold increases in plasma NH/sub 3/ levels. Exposure to sublethal concentration of a solution of the 13 major inorganic constituents of Omega-9 water also decreased pcv and plasma AP activity and increased plasma NH/sub 3/ levels. No sublethal effects on blood HB, protein, and alkaline phosphatase occurred at a toxic level <1/5 of the level of the LC50.

  20. Western oil-shale development: a technology assessment. Volume 5: an investigation of dewatering for the modified in-situ retorting process, Piceance Creek Basin, Colorado

    SciTech Connect

    Not Available

    1982-01-01

    The C-a and the C-b tracts in the Piceance Creek Basin are potential sites for the development of oil shale by the modified in-situ retorting (MIS) process. Proposed development plans for these tracts require the disturbance of over three billion m/sup 3/ of oil shale to a depth of about 400 m (1312 ft) or more below ground level. The study investigates the nature and impacts of dewatering and reinvasion that are likely to accompany the MIS process. The purpose is to extend earlier investigations through more refined mathematical analysis. Physical phenomena not adequately covered in previous studies, particularly the desaturation process, are investigated. The present study also seeks to identify, through a parametric approach, the key variables that are required to characterize systems such as those at the C-a and C-b tracts.

  1. Method of operating an oil shale kiln

    DOEpatents

    Reeves, Adam A.

    1978-05-23

    Continuously determining the bulk density of raw and retorted oil shale, the specific gravity of the raw oil shale and the richness of the raw oil shale provides accurate means to control process variables of the retorting of oil shale, predicting oil production, determining mining strategy, and aids in controlling shale placement in the kiln for the retorting.

  2. Quenching and stabilization of MIS retorts: Bench-scale experiments

    SciTech Connect

    Barbour, F.A.; Boysen, J.E.

    1991-04-01

    This research was conducted to evaluate in situ retort stabilization methods. The objective of the bench-scale simulations was to evaluate possible post-retorting operations procedures for the optimum cleaning of spent retorts. After simulating conditions of modified in situ (MIS) retorts at the time retorting had ended, procedures to accelerate retort cleanup without using large volumes of water were investigated. Samples from various levels of the retort were used to determine the amount of water-soluble constituents in the spent shale and the rehydration characteristics of the spent shale. The organic material that remained after retorting was most effectively removed from the retort by the use of reverse combustion. The removal of the organic material in this manner cracked the oil on the unretorted shale and removed heat from the bottom of the retort. Both were then transported toward the top of the retort. Unretorted kerogen was coked as it emerged from the shale near the reverse-combustion front. The reverse-combustion technique had an additional benefit in that the carbon deposited on the spent shale in the combusted zone appeared to provide a barrier to rehydration of the shale on introduction of water into the retorts. A hot quench immediately following retorting was also relatively effective in removing organic material from the retort. However, the quench did leave some organic material on the unretorted shale. This material was not readily removed by water leaching during laboratory testing. A deluge of water on a cool retort did not efficiently remove the organic material from the unretorted shale nor did the addition of a biodegradable detergent.

  3. Method for maximizing shale oil recovery from an underground formation

    DOEpatents

    Sisemore, Clyde J.

    1980-01-01

    A method for maximizing shale oil recovery from an underground oil shale formation which has previously been processed by in situ retorting such that there is provided in the formation a column of substantially intact oil shale intervening between adjacent spent retorts, which method includes the steps of back filling the spent retorts with an aqueous slurry of spent shale. The slurry is permitted to harden into a cement-like substance which stabilizes the spent retorts. Shale oil is then recovered from the intervening column of intact oil shale by retorting the column in situ, the stabilized spent retorts providing support for the newly developed retorts.

  4. Methodology and concepts for the design of surface storage fills at the Anvil Points Oil Shale Retort Facility

    SciTech Connect

    Strohm, W.E. Jr.; Krinitzsky, E.L.

    1983-12-01

    Primary obtectives in design of surface disposal fills for processed and raw oil shales are: (a) to insure long-term physical stability, and (b) to prevent surface runoff, surface erosion, and possible subsurface seepage from degrading the water quality of streams and ground water, it was concluded that the analysis and design of spent shale disposal fills should be based on sound geotechnical engineeering principles, considerable experience, and good judgment. An understanding of the source of variability of spent shale materials and its effect on engineering properties is a first step in developing fill design. A second important step is the assessment of long-term changes in the properties of spent shale within a disposal fill. This assessment requires consideration of possible thermal, hydrochemical, and physical interactions within the fill and between the fill and site environment. The site environment is site-specific and depends on the geological, surface and subsurface hydrological, and geotechnical characteristics of the site. The variability of spent shale materials is a direct function of variations in mineral and chemical composition of the raw shale and of the processes applied. Current technology for the design and construction of spent shale disposal fills has not been proven by experience. A major problem is the large quantities of spent shale generated for surface disposal and the lack of available sites other than large gulches in the oil shale country of the western United States. Conceptual research fill designs developed in this study should be refined and constructed to provide needed information on in situ properties and long-term performance. Research fills planned by others should be augmented to obtain needed information, especially for codisposal of spent shales with treated waste water, raw shale fines, and process dust.

  5. Assessment of transport processes using a combined pyrolysis-combustion model for the retorting of oil shale

    SciTech Connect

    Crowl, D.A.; Piccirelli, R.A.

    1982-09-01

    A mathematical model is developed to represent the coupled mass and energy transport effects of simultaneous pyrolysis and combustion processes occurring within a single piece of consolidated oil shale. Major emphasis is placed on assessing the relative importance of the coupled transport processes. Numerical solution of the resulting equations using Antrim oil shale parameters show a number of important effects. First, it is possible for the combustion oxygen to diffuse against the outgoing stream of pyrolysis products. Thus, simultaneous pyrolysis and combustion fronts can occur within the same localized region of shale. Second, the heat generated at the combustion front can conduct through the solid shale to the pyrolysis zone. This leads to a substantial increase in pyrolysis activity.

  6. Energy from true in situ processing of Antrim shale: preparation of an in situ retort bed by hydraulic fracturing

    SciTech Connect

    Peil, C.A.

    1980-05-01

    Under these specific field conditions, utilization of the natural tendency of the formation to fracture vertically provided the basis for this revised experiment. Observations made during hydrofracturing and permeability testing indicate that a complicated but extensive fracture system exists in the 100 series wells. An efficient and effective borehole loading system was developed after considerable effort. Borehole explosives improved permeability and communications significantly over that which existed before explosive fracturing. The use of hydrofractured and propped fractures was effective and dramatically demonstrated by cement traversing from one well to another. Fluid control remained a problem and would become more significant during any in situ retorting trials. The results of this experiment are encouraging when compared with those experienced in our front site test area. However, on the basis of better fluid control, overall communications and a wider range of operating pressures, the explosive underream and fracturing experiment was chosen as the site for the in situ extraction trial. No further work is planned on this task.

  7. Combined fluidized bed retort and combustor

    DOEpatents

    Shang, Jer-Yu; Notestein, John E.; Mei, Joseph S.; Zeng, Li-Wen

    1984-01-01

    The present invention is directed to a combined fluidized bed retorting and combustion system particularly useful for extracting energy values from oil shale. The oil-shale retort and combustor are disposed side-by-side and in registry with one another through passageways in a partition therebetween. The passageways in the partition are submerged below the top of the respective fluid beds to preclude admixing or the product gases from the two chambers. The solid oil shale or bed material is transported through the chambers by inclining or slanting the fluidizing medium distributor so that the solid bed material, when fluidized, moves in the direction of the downward slope of the distributor.

  8. Energy from true in situ processing of antrim shale: preparation of in situ retort bed by explosive underreaming and fracturing

    SciTech Connect

    Peil, C.A.

    1980-07-01

    This report summarizes the work carried out on the explosive underream and fracturing of Antrim shale. This experiment involved the creation of a cavity in the shale by detonating successively larger explosive shots in a central wellbore. Two more wells were located, drilled and cored 15 feet either side of the central well. Core analysis of these wells indicated that one well had a high concentration of fractures which were likely induced explosively, while the other well had few fractures thought to have been explosively induced. Interwell communication established by fluid injection confirmed the differences. A gyroscopic survey of the borehole shed some light on this difference. The well containing the extensive fracturing remained 15 feet from the bottom of the central well, while the distance to the second well had increased 63%. The wells were loaded with a slurry explosive system and detonated. The wellbores were cleaned out and the results were evaluated with flow logging, air permeability, tracer gas, differential temperature, borehole television and vertical seismic profiling techniques. The results defined the degree of interwell communications, the location of major fractures, and indicated that five of the seven wells were in some degree of communication. The major zone of permeability was through vertical fractures forming a wedge between three of the wells. An effective system for monitoring and pumping of formation fluids was designed and installed. The results of a post-fracture vertical seismic profile survey corroborated other logging techniques and confirmed the existence of a complex fracture system at depths ranging from 1230 to 1375 feet. The fracture system was defined as being a larger planer zone, 70 to 100 feet wide and 70 to 100 feet high.

  9. Pyritic waste from precombustion coal cleaning: Amelioration with oil shale retort waste and sewage sludge for growth of soya beans

    SciTech Connect

    Lewis, B.G.; Gnanapragasam, N.; Stevens, M.L.

    1994-12-31

    Solid residue from fossil fuel mining and utilization generally present little hazard to human health. However, because of the high volumes generated, they do pose unique disposal problems in terms of land use and potential degradation of soil and water. In the specific case of wastes from precombustion coal cleaning, the materials include sulfur compounds that undergo oxidation when exposed to normal atmospheric conditions and microbial action and then produce sulfuric acid. The wastes also contain compounds of metals and nonmetals at concentrations many times those present in the original raw coal. Additionally, the residues often contain coal particles and fragments that combust spontaneously if left exposed to the air, thus contributing to the air pollution that the coal cleaning process was designed to prevent. Federal and state efforts in the United States to ameliorate the thousands of hectares covered with these wastes have focused on neutralizing the acidity with limestone and covering the material with soil. The latter procedure creates additional degraded areas, which were originally farmland or wildlife habitat. It would seem preferable to reclaim the coal refuse areas without earth moving. The authors describe here experiments with neutralization of coal waste acidity using an alkaline waste derived from the extraction of oil from oil shale to grow soya beans (Glycine max. [L]) on a mixture of wastes and sewage sludge. Yield of plant material and content of nutrients an potentially toxic elements in the vegetation and in the growth mixtures were determined; results were compared with those for plants grown on an agricultural soil, with particular focus on boron.

  10. Revegetation research on oil shale lands in the Piceance Basin

    SciTech Connect

    Redente, E.F.; Cook, C.W.

    1981-02-01

    The overall objective of this project is to study the effects of various reclamation practices on above- and belowground ecosystem development associated with disturbed oil shale lands in northwestern Colorado. Plant growth media that are being used in field test plots include retorted shale, soil over retorted shale, subsoil materials, and surface disturbed topsoils. Satisfactory stands of vegetation failed to establish on unleached retorted shale during two successive years of seeding. All seedings with soil over retorted shale were judged to be successful at the end of three growing seasons, but deep-rooted shrubs that depend upon subsoil moisture may have their growth hampered by the retorted shale substrate. Natural revegetation on areas with various degrees of disturbance shows that natural invasion and succession was slow at best. Invasion of species on disturbed topsoil plots showed that after three years introduced seed mixtures were more effective than native mixtures in occupying space and closing the community to invading species. Fertilizer appears to encourage the invasion of annual plants even after the third year following application. Long-term storage of topsoil without vegetation significantly decreases the mycorrhizal infection potential and, therefore, decreases the relative success of aboveground vegetation and subsequent succession. Ecotypic differentation related to growth and competitive ability, moisture stress tolerance, and reproductive potential have been found in five native shrub species. Germplasm sources of two grasses and two legumes, that have shown promise as revegetation species, have been collected and evaluated for the production of test seed. Fertilizer (nitrogen) when added to the soil at the time of planting may encourage competition from annual weeds to the detriment of seeded species.

  11. Location of potential interest for fracturing oil shale with nuclear explosives for in situ retorting, Piceance Creek Basin, Rio Blanco County, Colorado

    USGS Publications Warehouse

    Ege, J.R.

    1967-01-01

    Analysis of oil assays, structure sections, and isopach maps of the Parachute Creek Member of the Green River Formation indicates that numerous locations in the western part of the Piceance Creek basin could be selected with an oil shale section at least 500 feet thick that contains not less than 20 gallons per ton of shale oil, and has at least 800 feet of overburden.

  12. Plant response to aqueous effluents derived from in-situ fossil-fuel processing. Part III. Three grass species and their response to Omega 9 and to five produced retort waters: oil shale, tar sands and underground coal gasification. [Basin wildrye; western wheatgrass; alkali sacaton

    SciTech Connect

    Skinner, Q.D.

    1981-12-01

    In situ produced waters collected from retorting oil shale and tar sands to produce oil and in-situ coal gasification to produce gas were tested for their effect on plant growth. Three native grass plant species were utilized for monitoring growth response. Root weight, shoot weight, total dry weight, leaf area, root/shoot ratio and shoot/leaf area ratio were parameters measured. All experiments were conducted under greenhouse conditions using hydroponic techniques and commercial grade perlite as support systems. Measurements were collected after a 10-week growth period. The hypothesis tested was, there is a difference between produced waters diluted by ground water and those where dilution is non-existent and their effect on plant growth. Results indicated that retort water diluted by ground water has a less toxic effect on plant species tested.

  13. Plant response to aqueous effluents derived from in-situ fossil-fuel processing. Part II. Five grass plant species and their response to five produced retort waters: oil shale, tar sands, and underground coal gasification. [Wildrye; wheatgrass; alkali sacaton; alkaligrass

    SciTech Connect

    Skinner, Q.D.

    1981-11-01

    In situ produced waters collected from retorting oil shale and tar sands to produce oil and in-situ coal gasification to produce gas were tested for their effect on plant growth. Five native grass plant species were utilized for monitoring growth response. Root weight, shoot weight, total dry weight, leaf area, root/shoot ratio and shoot/leaf area ratio were parameters measured. All experiments were conducted under greenhouse conditions using hydroponic techniques and commercial grade perlite as support systems. Measurements were collected after a 10 week growth period. Hypotheses tested were: (a) there is a difference between in situ produced waters, and (b) plant species respond differently to various retort waters. Results indicated that the stated hypotheses were true.

  14. Explosively produced fracture of oil shale. Progress report, January to March 1981

    SciTech Connect

    Not Available

    1982-01-01

    This is the first Los Alamos Oil Shale progress report in a new format, designed to continue the publication of technical papers each quarter and to report the progress made each quarter in oil shale research. This first report describes the history of the project to put the present status in perspective and outlines the program and its objectives. In subsequent reports, program achievements will be reported along with the usual technical papers. Section I covers program management, explosive characterization, dynamic rock mechanics, field verification tests, and stress wave, fluid flow, and retort stabiliy modeling. Program history, recent accomplishments, and future plans are discussed for each program element. Details are also given on how the program dovetails with that of industry, particularly with the Oil Shale Consortium. Finally, the unique operational principles and field applications of the CORRTEX system to oil shale field experiments are explained. Section II presents several technical papers. An overview of the rock fragmentation effort to enhance the permeability of oil shale using explosives summarizes the project, its rationale, and objectives. Results of explosive characterization tests show that the maximum pressure and gas drive of ANFO are greatly enhanced by the addition of aluminum. In fracture modeling, spallation is studied in terms of crack growth, and the effect of anisotropy in explosive fragmentation is calculated and compared with radiograph data from field tests. Our TRACER model is explained and fluid flow calculations for heat and mass transfer in the Occidental Oil Shale, Inc. MR-3 retort are shown to compare well with field data. Also, the status of the two-dimensional retorting model, which fully couples retort chemistry with fluid dynamics, is given.

  15. The development of an integrated multistage fluid bed retorting process. Annual report, September 1990--September 1991

    SciTech Connect

    Carter, S.; Vego, A.; Taulbee, D.; Stehn, J.

    1992-01-01

    This report summarizes the progress made on the development of an integrated multistage fluidized bed retorting process (KENTORT II). The KENTORT II process includes integral fluidized bed zone for pyrolysis, gasification, and combustion of the oil shale. The purpose of this program is to design and test the KENTORT II process at the 50-lb/hr scale. The work performed during this year involved projects that will contribute physical and chemical data for the final design of the 50-lb/hr retort. A cold-flow model of the 50-lb/hr retort was built and tested. The unit demonstrated stable operation and proper fluidization of all beds. Good control of solid recirculation up to the maximum design rate for each loop (200 and 500 lb/hr, respectively) was achieved simultaneously. Basically, the cold-flow model is completely operational and translation of the cold-flow design parameters to the design of the retort is ready to begin. In another aspect of the program, a study of the cracking and coking kinetics of shale oil vapors passed over processed shales was initiated. The addition of a mass spectrometer to the system to monitor total carbon, nitrogen and sulfur evolution in real-time was successful. Coking activities of processed shales were ranked as follows: combusted shale > gasified shale > pyrolyzed shale. Arrangements for conducting an evaluation of KENTORT-derived oil for asphalt applications were finalized and testing was initiated.

  16. Shale oil recovery process

    DOEpatents

    Zerga, Daniel P.

    1980-01-01

    A process of producing within a subterranean oil shale deposit a retort chamber containing permeable fragmented material wherein a series of explosive charges are emplaced in the deposit in a particular configuration comprising an initiating round which functions to produce an upward flexure of the overburden and to initiate fragmentation of the oil shale within the area of the retort chamber to be formed, the initiating round being followed in a predetermined time sequence by retreating lines of emplaced charges developing further fragmentation within the retort zone and continued lateral upward flexure of the overburden. The initiating round is characterized by a plurality of 5-spot patterns and the retreating lines of charges are positioned and fired along zigzag lines generally forming retreating rows of W's. Particular time delays in the firing of successive charges are disclosed.

  17. WATER COOLED RETORT COVER

    DOEpatents

    Ash, W.J.; Pozzi, J.F.

    1962-05-01

    A retort cover is designed for use in the production of magnesium metal by the condensation of vaporized metal on a collecting surface. The cover includes a condensing surface, insulating means adjacent to the condensing surface, ind a water-cooled means for the insulating means. The irrangement of insulation and the cooling means permits the magnesium to be condensed at a high temperature and in massive nonpyrophoric form. (AEC)

  18. Adsorption, Permeability, and Effective Stress in the Barnett Shale, Texas, USA

    NASA Astrophysics Data System (ADS)

    Vermylen, J. P.; Zoback, M. D.

    2010-12-01

    We have been carrying out adsorption and permeability experiments on Barnett shale core samples. For our adsorption work, we seek to understand how rock properties control gas adsorption and also to investigate the potential for carbon dioxide sequestration and enhanced recovery in gas shale rocks. Adsorption experiments have been conducted on crushed, dried Barnett samples using conventional Boyle’s law methods. Langmuir-like adsorption curves have been measured for nitrogen, methane, and carbon dioxide. At 5 MPa (725 psi), N2 adsorption ranges between 0.3-0.5 cc/g (10-17 scf/ton), CH4 adsorption ranges between 0.7-1.1 cc/g (25-40 scf/ton), and CO2 adsorption ranges between 2.5-3.5 cc/g (90-125 scf/ton). These results are consistent with previous analyses of Barnett shale samples and Appalachian shale samples of similar composition. We observe about 3x adsorption of CO2 over CH4 in the Barnett Shale, however, further research is required to investigate the potential for enhanced production of methane with CO2 in these rocks. Our permeability experiments are focused on building effective stress laws for gas shales and investigating the effects of different gases, both adsorbing and non-adsorbing, on permeability. Permeability experiments have been conducted on intact rock plugs using pulse-permeability and static darcy flow methods. We have measured permeabilities ranging from 1500 to 5 nanodarcies on intact samples, both 10x higher and 10x lower than the widely reported 100 nanodarcy average Barnett Shale intact matrix permeability. On a higher permeability shale sample with a carbonate streak, the effective stress coefficient for permeability was found to be 0.82, indicating a moderate impact of pore pressure on permeability. Work to characterize effective stress laws for the lowest permeability samples is ongoing, as is the effect of adsorbing gases on permeability in the Barnett shale.

  19. Plan and justification for a Proof-of-Concept oil shale facility. Final report

    SciTech Connect

    Not Available

    1990-12-01

    The technology being evaluated is the Modified In-Situ (MIS) retorting process for raw shale oil production, combined with a Circulating Fluidized Bed Combustor (CFBC), for the recovery of energy from the mined shale. (VC)

  20. Plan and justification for a Proof-of-Concept oil shale facility

    SciTech Connect

    Not Available

    1990-12-01

    The technology being evaluated is the Modified In-Situ (MIS) retorting process for raw shale oil production, combined with a Circulating Fluidized Bed Combustor (CFBC), for the recovery of energy from the mined shale. (VC)

  1. Environmental research on a modified in situ oil shale task process. Progress report

    SciTech Connect

    Not Available

    1980-05-01

    This report summarizes the progress of the US Department of Energy's Oil Shale Task Force in its research program at the Occidental Oil Shale, Inc. facility at Logan Wash, Colorado. More specifically, the Task Force obtained samples from Retort 3E and Retort 6 and submitted these samples to a variety of analyses. The samples collected included: crude oil (Retort 6); light oil (Retort 6); product water (Retort 6); boiler blowdown (Retort 6); makeup water (Retort 6); mine sump water; groundwater; water from Retorts 1 through 5; retort gas (Retort 6); mine air; mine dust; and spent shale core (Retort 3E). The locations of the sampling points and methods used for collection and storage are discussed in Chapter 2 (Characterization). These samples were then distributed to the various laboratories and universities participating in the Task Force. For convenience in organizing the data, it is useful to group the work into three categories: Characterization, Leaching, and Health Effects. While many samples still have not been analyzed and much of the data remains to be interpreted, there are some preliminary conclusions the Task Force feels will be helpful in defining future needs and establishing priorities. It is important to note that drilling agents other than water were used in the recovery of the core from Retort 3E. These agents have been analyzed (see Table 12 in Chapter 2) for several constituents of interest. As a result some of the analyses of this core sample and leachates must be considered tentative.

  2. Stress dependence of permeability of intact and fractured shale cores.

    NASA Astrophysics Data System (ADS)

    van Noort, Reinier; Yarushina, Viktoriya

    2016-04-01

    Whether a shale acts as a caprock, source rock, or reservoir, understanding fluid flow through shale is of major importance for understanding fluid flow in geological systems. Because of the low permeability of shale, flow is thought to be largely confined to fractures and similar features. In fracking operations, fractures are induced specifically to allow for hydrocarbon exploration. We have constructed an experimental setup to measure core permeabilities, using constant flow or a transient pulse. In this setup, we have measured the permeability of intact and fractured shale core samples, using either water or supercritical CO2 as the transporting fluid. Our measurements show decreasing permeability with increasing confining pressure, mainly due to time-dependent creep. Furthermore, our measurements show that for a simple splitting fracture, time-dependent creep will also eliminate any significant effect of this fracture on permeability. This effect of confinement on fracture permeability can have important implications regarding the effects of fracturing on shale permeability, and hence for operations depending on that.

  3. Effects of rock mineralogy and pore structure on stress-dependent permeability of shale samples.

    PubMed

    Al Ismail, Maytham I; Zoback, Mark D

    2016-10-13

    We conducted pulse-decay permeability experiments on Utica and Permian shale samples to investigate the effect of rock mineralogy and pore structure on the transport mechanisms using a non-adsorbing gas (argon). The mineralogy of the shale samples varied from clay rich to calcite rich (i.e. clay poor). Our permeability measurements and scanning electron microscopy images revealed that the permeability of the shale samples whose pores resided in the kerogen positively correlated with organic content. Our results showed that the absolute value of permeability was not affected by the mineral composition of the shale samples. Additionally, our results indicated that clay content played a significant role in the stress-dependent permeability. For clay-rich samples, we observed higher pore throat compressibility, which led to higher permeability reduction at increasing effective stress than with calcite-rich samples. Our findings highlight the importance of considering permeability to be stress dependent to achieve more accurate reservoir simulations especially for clay-rich shale reservoirs.This article is part of the themed issue 'Energy and the subsurface'. PMID:27597792

  4. Effects of rock mineralogy and pore structure on stress-dependent permeability of shale samples.

    PubMed

    Al Ismail, Maytham I; Zoback, Mark D

    2016-10-13

    We conducted pulse-decay permeability experiments on Utica and Permian shale samples to investigate the effect of rock mineralogy and pore structure on the transport mechanisms using a non-adsorbing gas (argon). The mineralogy of the shale samples varied from clay rich to calcite rich (i.e. clay poor). Our permeability measurements and scanning electron microscopy images revealed that the permeability of the shale samples whose pores resided in the kerogen positively correlated with organic content. Our results showed that the absolute value of permeability was not affected by the mineral composition of the shale samples. Additionally, our results indicated that clay content played a significant role in the stress-dependent permeability. For clay-rich samples, we observed higher pore throat compressibility, which led to higher permeability reduction at increasing effective stress than with calcite-rich samples. Our findings highlight the importance of considering permeability to be stress dependent to achieve more accurate reservoir simulations especially for clay-rich shale reservoirs.This article is part of the themed issue 'Energy and the subsurface'.

  5. The development of an integrated multistage fluid bed retorting process. [KENTORT II process--50-lb/hr

    SciTech Connect

    Carter, S.; Vego, A.; Taulbee, D.; Stehn, J.

    1992-01-01

    This report summarizes the progress made on the development of an integrated multistage fluidized bed retorting process (KENTORT II). The KENTORT II process includes integral fluidized bed zone for pyrolysis, gasification, and combustion of the oil shale. The purpose of this program is to design and test the KENTORT II process at the 50-lb/hr scale. The work performed during this year involved projects that will contribute physical and chemical data for the final design of the 50-lb/hr retort. A cold-flow model of the 50-lb/hr retort was built and tested. The unit demonstrated stable operation and proper fluidization of all beds. Good control of solid recirculation up to the maximum design rate for each loop (200 and 500 lb/hr, respectively) was achieved simultaneously. Basically, the cold-flow model is completely operational and translation of the cold-flow design parameters to the design of the retort is ready to begin. In another aspect of the program, a study of the cracking and coking kinetics of shale oil vapors passed over processed shales was initiated. The addition of a mass spectrometer to the system to monitor total carbon, nitrogen and sulfur evolution in real-time was successful. Coking activities of processed shales were ranked as follows: combusted shale > gasified shale > pyrolyzed shale. Arrangements for conducting an evaluation of KENTORT-derived oil for asphalt applications were finalized and testing was initiated.

  6. System for utilizing oil shale fines

    DOEpatents

    Harak, Arnold E.

    1982-01-01

    A system is provided for utilizing fines of carbonaceous materials such as particles or pieces of oil shale of about one-half inch or less diameter which are rejected for use in some conventional or prior surface retorting process, which obtains maximum utilization of the energy content of the fines and which produces a waste which is relatively inert and of a size to facilitate disposal. The system includes a cyclone retort (20) which pyrolyzes the fines in the presence of heated gaseous combustion products, the cyclone retort having a first outlet (30) through which vapors can exit that can be cooled to provide oil, and having a second outlet (32) through which spent shale fines are removed. A burner (36) connected to the spent shale outlet of the cyclone retort, burns the spent shale with air, to provide hot combustion products (24) that are carried back to the cyclone retort to supply gaseous combustion products utilized therein. The burner heats the spent shale to a temperature which forms a molten slag, and the molten slag is removed from the burner into a quencher (48) that suddenly cools the molten slag to form granules that are relatively inert and of a size that is convenient to handle for disposal in the ground or in industrial processes.

  7. Solar heated oil shale pyrolysis process

    NASA Technical Reports Server (NTRS)

    Qader, S. A. (Inventor)

    1985-01-01

    An improved system for recovery of a liquid hydrocarbon fuel from oil shale is presented. The oil shale pyrolysis system is composed of a retort reactor for receiving a bed of oil shale particules which are heated to pyrolyis temperature by means of a recycled solar heated gas stream. The gas stream is separated from the recovered shale oil and a portion of the gas stream is rapidly heated to pyrolysis temperature by passing it through an efficient solar heater. Steam, oxygen, air or other oxidizing gases can be injected into the recycle gas before or after the recycle gas is heated to pyrolysis temperature and thus raise the temperature before it enters the retort reactor. The use of solar thermal heat to preheat the recycle gas and optionally the steam before introducing it into the bed of shale, increases the yield of shale oil.

  8. Model capabilities for in-situ oil shale recovery

    SciTech Connect

    Hommert, P.J.; Tyner, C.E.

    1980-01-01

    The extensive oil shale reserves of the United States are now under development as an energy source. One of the approaches for extracting oil from shale is the so-called modified in-situ retort. The operation of such retorts for maximum yield requires an understanding of oil loss mechanisms so that operating strategies that minimize these losses can be developed. The present modeling capabilities for describing the behavior and yield from a modified in-situ retort are discussed. It is shown how the advances made in describing retort chemistry have greatly increased the predictive capabilities of these models. Two models that have been subject to comparison with laboratory retorts are described. The first is a one-dimensional model that treats the retort as a packed bed reactor, the second is a quasi-two-dimensional examination of block retorting. Both models are capable of predicting retorting rates, off gas composition and oil yield losses to coking and combustion. The block model, for example, describes conditions where local oil yield losses can be as high as 50%. Areas for further model improvement include additional work on describing retort chemistry, such as the steam/char and gas phase combustion reactions. The major need for modeling now is expansion to multi-dimensional simulation. This is necessary if a predictive capability is to be developed for field situations where sweep efficiency losses and gravitational effects become important.

  9. Oil shale commercialization study

    SciTech Connect

    Warner, M.M.

    1981-09-01

    Ninety four possible oil shale sections in southern Idaho were located and chemically analyzed. Sixty-two of these shales show good promise of possible oil and probable gas potential. Sixty of the potential oil and gas shales represent the Succor Creek Formation of Miocene age in southwestern Idaho. Two of the shales represent Cretaceous formations in eastern Idaho, which should be further investigated to determine their realistic value and areal extent. Samples of the older Mesozonic and paleozoic sections show promise but have not been chemically analyzed and will need greater attention to determine their potential. Geothermal resources are of high potential in Idaho and are important to oil shale prospects. Geothermal conditions raise the geothermal gradient and act as maturing agents to oil shale. They also might be used in the retorting and refining processes. Oil shales at the surface, which appear to have good oil or gas potential should have much higher potential at depth where the geothermal gradient is high. Samples from deep petroleum exploration wells indicate that the succor Creek shales have undergone considerable maturation with depth of burial and should produce gas and possibly oil. Most of Idaho's shales that have been analyzed have a greater potential for gas than for oil but some oil potential is indicated. The Miocene shales of the Succor Creek Formation should be considered as gas and possibly oil source material for the future when technology has been perfectes. 11 refs.

  10. Characterization of mercury, arsenic, and selenium in the product streams of the Pacific Northwest Laboratory 6-kg retort

    SciTech Connect

    Olsen, K.B.; Evans, J.C.; Sklarew, D.S.; Girvin, D.C.; Nelson, C.L.; Lepel, E.A.; Robertson, D.E.; Sanders, R.W.

    1985-12-01

    The objective of this program is to determine how retorting process parameters affect the partitioning of Hg, As, Se, and Cd from raw oil shale to spent shale, shale oil, retort water, and offgas. For each of the elements, the objective of this study is to (1) determine the distribution coefficients for each product stream; (2) identify the chemical forms in water, gas, and oil streams, with particular emphasis on inorganic or organometallic species known to be or suspected of being carcinogenic, toxic, or otherwise harmful; (3) investigate the mechanism(s) responsible for mobilization into each product stream for toxic or labile chemical forms identified in item 2 are mobilized into each product stream; and (4) the effect of retorting rate, maximum retorting temperature, and retorting atmosphere on items 1 and 3. A Green River shale from Colorado and a New Albany shale from Kentucky were heated at 1 to 2/sup 0/C/min and at 10/sup 0/C/min to maximum temperatures of 500 and 750/sup 0/C under a nitrogen sweep gas. The product streams were analyzed using a variety of methods including Zeeman atomic absorption spectroscopy, microwave-induced helium plasma spectroscopy, x-ray fluorescence, instrumental neutron activation analysis, high-pressure liquid and silica gel column chromatography, and mercury cold vapor atomic absorption. The results obtained using these analytical methods indicate that the distribution of mercury, arsenic, and selenium in the product stream is a function of oil shale type, heating rates, and maximum retorting temperatures. 11 refs., 27 figs., 5 tabs.

  11. Correlations for the diffusivity and permeability for Devonian shale

    SciTech Connect

    Cannon, T.J.; Johnston, D.A.; Fogler, H.S.; Schultz, J.S.

    1980-07-01

    Energy extraction from oil shale is a major facet of the expanding synthetic fuels program. In situ retorting of oil shale presents a method of recovering a portion of that stored energy content by inducing a flame front through the shale. Diffusivity and permeability are measures of the ease of movement of air toward the flame front and product gases away from the front. This study reports on measurements of diffusivity and permeability at seven depths within and below the Antrim shale for unretorted and retorted cores. The threshold pressures were also measured and compared to the predictions given by correlations. Finally, correlations were developed between the diffusivity, permeability and other physical properties.

  12. INVESTIGATIONS ON HYDRAULIC CEMENTS FROM SPENT OIL SHALE

    SciTech Connect

    Mehta, P.K.; Persoff, P.

    1980-04-01

    A process for making hydraulic cements from spent oil shale is described in this paper. Inexpensive cement is needed to grout abandoned in-situ retorts of spent shale for subsidence control, mitigation of leaching, and strengthening the retorted mass in order to recover oil from adjacent pillars of raw shale. A hydraulic cement was produced by heating a 1:1 mixture of Lurgi spent shale and CaCO{sub 3} at 1000 C for one hour. This cement would be less expensive than ordinary portland cement and is expected to fulfill the above requirements.

  13. Role of spent shale in oil shale processing and the management of environmental residues. Final technical report, January 1979-May 1980

    SciTech Connect

    Hines, A.L.

    1980-08-15

    The adsorption of hydrogen sulfide on retorted oil shale was studied at 10, 25, and 60/sup 0/C using a packed bed method. Equilibrium isotherms were calculated from the adsorption data and were modeled by the Langmuir, Freundlich, and Polanyi equations. The isosteric heat of adsorption was calculated at three adsorbent loadings and was found to increase with increased loading. A calculated heat of adsorption less than the heat of condensation indicated that the adsorption was primarily due to Van der Waals' forces. Adsorption capacities were also found as a function of oil shale retorting temperature with the maximum uptake occurring on shale that was retorted at 750/sup 0/C.

  14. LLNL oil shale project review

    SciTech Connect

    Cena, R.J.

    1990-04-01

    Livermore's oil shale project is funded by two budget authorities, two thirds from base technology development and one third from environmental science. Our base technology development combines fundamental chemistry research with operation of pilot retorts and mathematical modeling. We've studied mechanisms for oil coking and cracking and have developed a detailed model of this chemistry. We combine the detailed chemistry and physics into oil shale process models (OSP) to study scale-up of generic second generation Hot-Recycled-Solid (HRS) retorting systems and compare with results from our 4 tonne-per-day continuous-loop HRS pilot retorting facility. Our environmental science program focuses on identification of gas, solid and liquid effluents from oil shale processes and development of abatement strategies where necessary. We've developed on-line instruments to quantitatively measure trace sulfur and nitrogen compounds released during shale pyrolysis and combustion. We've studied shale mineralogy, inorganic and organic reactions which generate and consume environmentally sensitive species. Figures, references, and tables are included with each discussion.

  15. Attrition and abrasion models for oil shale process modeling

    SciTech Connect

    Aldis, D.F.

    1991-10-25

    As oil shale is processed, fine particles, much smaller than the original shale are created. This process is called attrition or more accurately abrasion. In this paper, models of abrasion are presented for oil shale being processed in several unit operations. Two of these unit operations, a fluidized bed and a lift pipe are used in the Lawrence Livermore National Laboratory Hot-Recycle-Solid (HRS) process being developed for the above ground processing of oil shale. In two reports, studies were conducted on the attrition of oil shale in unit operations which are used in the HRS process. Carley reported results for attrition in a lift pipe for oil shale which had been pre-processed either by retorting or by retorting then burning. The second paper, by Taylor and Beavers, reported results for a fluidized bed processing of oil shale. Taylor and Beavers studied raw, retorted, and shale which had been retorted and then burned. In this paper, empirical models are derived, from the experimental studies conducted on oil shale for the process occurring in the HRS process. The derived models are presented along with comparisons with experimental results.

  16. Oil shale: Technology status report

    SciTech Connect

    Not Available

    1986-10-01

    This report documents the status of the US Department of Energy's (DOE) Oil Shale Program as of the end of FY 86. The report consists of (1) a status of oil shale development, (2) a description of the DOE Oil Shale Program, (3) an FY 86 oil shale research summary, and (4) a summary of FY 86 accomplishments. Discoveries were made in FY 86 about the physical and chemical properties and behavior of oil shales, process chemistry and kinetics, in situ retorting, advanced processes, and the environmental behavior and fate of wastes. The DOE Oil Shale Program shows an increasing emphasis on eastern US oil shales and in the development of advanced oil shale processing concepts. With the award to Foster Wheeler for the design of oil shale conceptual plants, the first step in the development of a systems analysis capability for the complete oil shale process has been taken. Unocal's Parachute Creek project, the only commercial oil shale plant operating in the United States, is operating at about 4000 bbl/day. The shale oil is upgraded at Parachute Creek for input to a conventional refinery. 67 refs., 21 figs., 3 tabs.

  17. Environmental control technology for shale oil wastewaters

    SciTech Connect

    Mercer, B.W.; Wakamiya, W.; Bell, N.E.; Mason, M.J.; Spencer, R.R.; English, C.J.; Riley, R.G.

    1982-09-01

    This report summarizes the results of studies conducted at Pacific Northwest Laboratory from 1976 to 1982 on environmental control technology for shale oil wastewaters. Experimental studies conducted during the course of the program were focused largely on the treatment and disposal of retort water, particularly water produced by in situ retorting of oil shale. Alternative methods were evaluated for the treatment and disposal of retort water and minewater. Treatment and disposal processes evaluated for retort water include evaporation for separation of water from both inorganic and organic pollutants; steam stripping for ammonia and volatile organics removal; activated sludge and anaerobic digestion for removal of biodegradable organics and other oxidizable substances; carbon adsorption for removal of nonbiodegradable organics; chemical coagulation for removal of suspended matter and heavy metals; wet air oxidation and solvent extraction for removal of organics; and land disposal and underground injection for disposal of retort water. Methods for the treatment of minewater include chemical processing and ion exchange for fluoride and boron removal. Preliminary cost estimates are given for several retort water treatment processes.

  18. 4. VIEW OF AREA EXCAVATED FOR ACCESS TO MERCURY RETORT. ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    4. VIEW OF AREA EXCAVATED FOR ACCESS TO MERCURY RETORT. VIEW SOUTH FROM RETORT. (OCTOBER, 1995) - McCormick Group Mine, Mercury Retort, East slope of Buckskin Mountain, Paradise Valley, Humboldt County, NV

  19. Hydraulic fracturing and associated stress modeling for the Eastern Gas Shales Project. Final report

    SciTech Connect

    Advani, S.H.

    1980-12-01

    Frac fluid flow, structure, and fracture mechanics simulations are developed for predicting and optimizing fracture dimensions and fluid leak-offs. Roles of in situ stress and material properties for possible vertical migration of fractures from the pay zone are discussed. Rationale for foam and dendritic fracturing experiments is presented along with numerical experiments for examining the phenomena of spalling of the fracture faces and conditions for secondary fracture initiation. Assignment of conventional, foam, cyrogenic, dendritic, and explosive fracturing treatments for specific reservoir properties is considered. Variables include fracture density and extent, shale thickness, in-situ stress gradients, energy assist mechanisms, well clean-up, shale-frac fluid interaction, proppant selection, and fracture height control. The analysis suggests that correlation with prevailing in situ stress gradients are promising diagnostic indicators for fracture treatment selection and design. In conclusion, the comprehensive development of an economical strategy requires extensive and controlled field testing with supporting predictive analyses of reservoir responses. Finite element modeling of reservoir in situ stress trajectories and the flow and fracture responses in the reservoir is recommended.

  20. Oil shale loss from a laboratory fluidized bed

    SciTech Connect

    Taylor, R.W.; Beavers, P.L.

    1989-03-01

    The rate of loss of dust from a laboratory scale fluidized bed of Green River oil shale has been measured. The rate of loss of dust from raw shale in the bed was approximately 1%/min for the first few minutes, and then decreased. The loss rate for retorted or burnt shale was 5 to 10 times higher. The rate for retorted and burned shale were nearly the same. The time required for a 10 wt% loss of mass was approximately 3 min for processed shale and 1 hour for raw shale. Particles left in the bed during fluidization lost sharp corners, but kept the original elongation. Dust lost by the bed has a very wide range of sizes, and demonstrated a strong bimodal distribution of sizes. The bimodal distribution of particles is interpreted as resulting from two mechanisms of dust generation: fracture and wear. Fracture of large particles sometimes produced fragments which were small enough to be blown out of the bed. These fragments were much larger than the individual mineral grains in the shale. The fracture mechanism was dominant in the case of raw shale. Dust in the smaller particle-size range was generated by wear. Wear was the dominant mechanisms in the case of burned shale, whereas, for retorted shale, nearly equal amounts of dust were generated by each mechanism. 13 refs., 8 figs., 6 tabs.

  1. Integrated Use of Fluidized Bed Technology for Oil Production from Oil Shale

    NASA Astrophysics Data System (ADS)

    Siirde, Andres; Martins, Ants

    The plant unit which consists of a fluidized bed retort and CFB furnace for burning the by-products of retorting (semicoke and semicoke gas) is presented in this paper. The oil shale retort consists of a fast fluidized bed shaft, coarse semicoke bit, semicoke separation chamber and cyclone for the separation of fine semicoke particles. The crashed oil shale and hot ash from the CFB ash separator are fed concurrently into the fast fluidized bed shaft. For fluidizing the mixture of oil shale and hot ash particles, the recycle semicoke gas is used. The pyrolysis of oil shale begins in fluidized bed and is completed in the semicoke separation chamber. The coarse semicoke particles are separated from fluidized bed directly while the medium size particles are separated from the gases in the semicoke separation chamber and the finest semicoke particles in the cyclone. All the fractions of semicoke from the fluidized bed retort and semicoke gas from the oil fractionator are burnt in the CFB furnace. The semicoke ash is separated from flue gases in the CFB ash separator. A part of separated hot ash is fed into the fluidized bed retort as a solid heat carrier material and the rest into the furnace through the ash cooler or separated from the process. The retention of sulphur dioxide formed during the semicoke and semicoke gas combustion, is guaranteed for about 99 % due to the high CaO content in the semicoke ash and convenient temperature (about 850°C) in the CFB furnace. The described plant unit is useful for retorting oil shale and other solid hydrocarbon-containing fuels. The advantages of the present retorting process and system are: improved oil yield, greater throughput, lower retorting time, avoidance of moving parts in the retorting zones, reduced downtime, etc. A new plant unit for oil shale oil production has been elaborated and defended by the Estonian Utility Model EE 200700671 UI.

  2. Industrial hygiene aspects of underground oil shale mining

    SciTech Connect

    Hargis, K.M.; Jackson, J.O.

    1982-01-01

    Health hazards associated with underground oil shale mining are summarized in this report. Commercial oil shale mining will be conducted on a very large scale. Conventional mining techniques of drilling, blasting, mucking, loading, scaling, and roof bolting will be employed. Room-and-pillar mining will be utilized in most mines, but mining in support of MIS retorting may also be conducted. Potential health hazards to miners may include exposure to oil shale dusts, diesel exhaust, blasting products, gases released from the oil shale or mine water, noise and vibration, and poor environmental conditions. Mining in support of MIS retorting may in addition include potential exposure to oil shale retort offgases and retort liquid products. Based upon the very limited industrial hygiene surveys and sampling in experimental oil shale mines, it does not appear that oil shale mining will result in special or unique health hazards. Further animal toxicity testing data could result in reassessment if findings are unusual. Sufficient information is available to indicate that controls for dust will be required in most mining activities, ventilation will be necessary to carry away gases and vapors from blasting and diesel equipment, and a combination of engineering controls and personal protection will likely be required for control of noise. Recommendations for future research are included.

  3. Oil shale loss from a laboratory fluidized bed

    SciTech Connect

    Taylor, R.W.; Beavers, P.L. )

    1989-01-01

    The rate of loss of dust from a laboratory-scale fluidized bed of Greenriver oil shale has been measured. The rate of loss of dust form raw shale in the bed was approximately 1%/min for the first few minutes and then decreased. The loss rate for retorted or burnt shale was 5 to 10 times higher. The rates for retorted and burned shale were nearly the same. The time required for a 10 wt% loss of mass was approximately 3 min for processed shale and 1 hour for raw shale. Particles left in the bed during fluidization lost sharp corners, but kept the original elongation. Dust lost by the bed has a very wide range of sizes and demonstrated a strong bimodal distribution of sizes. The bimodal distribution of particles is interpreted as resulting from two mechanisms of dust generation; fracture and wear.

  4. Oil shales energy source development. Final report

    SciTech Connect

    Meyer, E.G.

    1983-01-18

    Oil shales represents the United States' second (after coal) most abundant fossil energy source. The Green River deposits in the West and the Devonian deposits in the East/Great Lakes are the principal oil shale deposits. This paper discusses in depth: the technology of recovering shale oil (retorting either above ground or in situ); refining of shale oil by hydrotreating and/or cracking; environmental impacts of retorting oil shales; economic analysis of shale oil refinery; and military applications of middle distillates from shale oils. At present the Parachute Creek, Colorado project of the Union Oil Company is the only active commercial scale shale oil project in operation. Union is building a 10,000 barrel per day plant at a cost of $600 million. The plant will be completed by midyear and be in operation by the end of 1983. The Department of Defense is guaranteeing a price of at least $42.50/barrel for the finished product, JP-4 jet fuel and diesel fuel made to military specifications. The overall conclusion that can be reached is that state-of-the-art, commercially practical refining processes are available to produce high quality fuels from shale oil at a cost which should make this resource a highly important part of our energy supply and therefore of our national security.

  5. Effects of organic wastes on water quality from processing of oil shale from the Green River Formation, Colorado, Utah, and Wyoming

    USGS Publications Warehouse

    Leenheer, J.A.; Noyes, T.I.

    1986-01-01

    A series of investigations were conducted during a 6-year research project to determine the nature and effects of organic wastes from processing of Green River Formation oil shale on water quality. Fifty percent of the organic compounds in two retort wastewaters were identified as various aromatic amines, mono- and dicarboxylic acids phenols, amides, alcohols, ketones, nitriles, and hydroxypyridines. Spent shales with carbonaceous coatings were found to have good sorbent properties for organic constituents of retort wastewaters. However, soils sampled adjacent to an in situ retort had only fair sorbent properties for organic constituents or retort wastewater, and application of retort wastewater caused disruption of soil structure characteristics and extracted soil organic matter constituents. Microbiological degradation of organic solutes in retort wastewaters was found to occur preferentially in hydrocarbons and fatty acid groups of compounds. Aromatic amines did not degrade and they inhibited bacterial growth where their concentrations were significant. Ammonia, aromatic amines, and thiocyanate persisted in groundwater contaminated by in situ oil shale retorting, but thiosulfate was quantitatively degraded one year after the burn. Thiocyanate was found to be the best conservative tracer for retort water discharged into groundwater. Natural organic solutes, isolated from groundwater in contact with Green River Formation oil shale and from the White River near Rangely, Colorado, were readily distinguished from organic constituents in retort wastewaters by molecular weight and chemical characteristic differences. (USGS)

  6. The Colony shale oil project

    SciTech Connect

    Hayes, L.D.

    1982-06-01

    The Colony shale oil project will be the first commercial shale oil plant in the US. It is located on the southern rim of the Piceance Creek Basin in Colorado, where half of the resources of the Green River basin lie. The process plant, the mine, the mining cycle, gyratory crushers, six Tosco II retorts, upgrading facilities, are all schematicized. Battlement Mesa, a town for employees, has been built at the base of the valley, where Parachute Creek confluences with the Colorado River. The amenities of Battlement Mesa are described.

  7. Comparison of the Acceptability of Various Oil Shale Processes

    SciTech Connect

    Burnham, A K; McConaghy, J R

    2006-03-11

    While oil shale has the potential to provide a substantial fraction of our nation's liquid fuels for many decades, cost and environmental acceptability are significant issues to be addressed. Lawrence Livermore National Laboratory (LLNL) examined a variety of oil shale processes between the mid 1960s and the mid 1990s, starting with retorting of rubble chimneys created from nuclear explosions [1] and ending with in-situ retorting of deep, large volumes of oil shale [2]. In between, it examined modified-in-situ combustion retorting of rubble blocks created by conventional mining and blasting [3,4], in-situ retorting by radio-frequency energy [5], aboveground combustion retorting [6], and aboveground processing by hot-solids recycle (HRS) [7,8]. This paper reviews various types of processes in both generic and specific forms and outlines some of the tradeoffs for large-scale development activities. Particular attention is given to hot-recycled-solids processes that maximize yield and minimize oil shale residence time during processing and true in-situ processes that generate oil over several years that is more similar to natural petroleum.

  8. The development of an integrated multistaged fluid-bed retorting process. Final report, September 1990--August 1994

    SciTech Connect

    Carter, S.D.; Taulbee, D.N.; Stehn, J.L.; Vego, A.; Robl, T.L.

    1995-02-01

    This summarizes the development of the KENTORT II retorting process, which includes integral fluidized bed zones for pyrolysis, gasification, and combustion of oil shale. Purpose was to design and test the process at the 50-lb/hr scale. The program included bench- scale studies of coking and cracking reactions of shale oil vapors over processed shale particles to address issues of scaleup associated with solid-recycle retorting. The bench-scale studies showed that higher amounts of carbon coverage reduce the rate of subsequent carbon deposition by shale oil vapors onto processed shale particles; however carbon-covered materials were also active in terms of cracking and coking. Main focus was the 50-lb/hr KENTORT II PDU. Cold-flow modeling and shakedown were done before the PDU was made ready for operation. Seven mass-balanced, steady-state runs were completed within the window of design operating conditions. Goals were achieved: shale feedrate, run duration (10 hr), shale recirculation rates (4:1 to pyrolyzer and 10:1 to combustor), bed temperatures (pyrolyzer 530{degree}C, gasifier 750{degree}C, combustor 830{degree}C), and general operating stability. Highest oil yields (up to 109% of Fischer assay) were achieved for runs lasting {ge} 10 hours. High C content of the solids used for heat transfer to the pyrolysis zone contributed to the enhanced oil yield achieved.

  9. The role of stress on chemical compaction of illite shale: An experimental study

    NASA Astrophysics Data System (ADS)

    Bruijn, R. H. C.; Almqvist, B. S. G.; Benson, P. M.; Hirt, A. M.

    2012-04-01

    Physical properties of basin sediments are strongly affected by diagenesis. For the case of shale diagenesis, the mechanical processes that dominate in the upper 2-3 km of sedimentary columns have been simulated in the laboratory. In contrast, chemical processes that dominate in deeper basin domains are poorly constrained by laboratory studies. In addition, the effect of tectonic forces has received little attention in physical experiments. We report on a series of compaction tests in which exposing the sample to well-controlled elevated temperature and pressure conditions relevant to deep basin-simulation activated chemical processes. We prepared our own synthetic samples by compacting illite shale powder into crystalline metapelite using a three-stage process, employing different stress fields to evaluate the effect of tectonic forces on compaction. In the first stage, dry powder (Maplewood Shale, New York, USA) was mechanically compacted in a hydraulic cold-press with a vertical load of 200 MPa. The second stage employed a hot isostatic press (HIP), set at 170 MPa confining pressure and 590 °C, to ensure powder lithification. In the final stage, further compaction was achieved by either repeating the HIP treatment or by performing confined deformation tests in a Paterson-type gas-medium apparatus. During the second HIP event, temperature and pressure were set at 490 °C and 172 MPa. Three different stress fields were applied in the Paterson apparatus: confined compression, confined torsion or isostatic stress. Deformation was enforced by applying a constant strain rate ranging from 7×10-6 to 7×10-4 s-1. Experiments were performed at 300 MPa confining pressure and a fixed temperature of 500 °C, 650 °C, 700 °C or 750 °C. These conditions were chosen based on a thermodynamic forward simulation of mineral stability fields. Compaction is quantified by connected porosity, anisotropy of magnetic susceptibility and mica texture strength. The synthetic metapelites

  10. Perform research in process development for hydroretorting of Eastern oil shales: Volume 2, Expansion of the Moving-Bed Hydroretorting Data Base for Eastern oil shales

    SciTech Connect

    Not Available

    1989-11-01

    An extensive data base was developed for six Eastern oil shales: Alabama Chattanooga, Indiana New Albany, Kentucky Sunbury, Michigan Antrim, Ohio Cleveland, and Tennessee Chattanooga shales. The data base included the hydroretorting characteristics of the six shales, as well as the retorting characteristics in the presence of synthesis gas and ionized gas. Shale gasification was also successfully demonstrated. Shale fines (20%) can produce enough hydrogen for the hydroretorting of the remaining 80% of the shale. The amount of fines tolerable in a moving bed was also determined. 16 refs., 59 figs., 43 tabs.

  11. Characterization of oil shale, isolated kerogen, and post-pyrolysis residues using advanced 13 solid-state nuclear magnetic resonance spectroscopy

    USGS Publications Warehouse

    Cao, Xiaoyan; Birdwell, Justin E.; Chappell, Mark A.; Li, Yuan; Pignatello, Joseph J.; Mao, Jingdong

    2013-01-01

    Characterization of oil shale kerogen and organic residues remaining in postpyrolysis spent shale is critical to the understanding of the oil generation process and approaches to dealing with issues related to spent shale. The chemical structure of organic matter in raw oil shale and spent shale samples was examined in this study using advanced solid-state 13C nuclear magnetic resonance (NMR) spectroscopy. Oil shale was collected from Mahogany zone outcrops in the Piceance Basin. Five samples were analyzed: (1) raw oil shale, (2) isolated kerogen, (3) oil shale extracted with chloroform, (4) oil shale retorted in an open system at 500°C to mimic surface retorting, and (5) oil shale retorted in a closed system at 360°C to simulate in-situ retorting. The NMR methods applied included quantitative direct polarization with magic-angle spinning at 13 kHz, cross polarization with total sideband suppression, dipolar dephasing, CHn selection, 13C chemical shift anisotropy filtering, and 1H-13C long-range recoupled dipolar dephasing. The NMR results showed that, relative to the raw oil shale, (1) bitumen extraction and kerogen isolation by demineralization removed some oxygen-containing and alkyl moieties; (2) unpyrolyzed samples had low aromatic condensation; (3) oil shale pyrolysis removed aliphatic moieties, leaving behind residues enriched in aromatic carbon; and (4) oil shale retorted in an open system at 500°C contained larger aromatic clusters and more protonated aromatic moieties than oil shale retorted in a closed system at 360°C, which contained more total aromatic carbon with a wide range of cluster sizes.

  12. High efficiency shale oil recovery

    SciTech Connect

    Adams, C.D.

    1992-07-18

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated at bench-scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although an oil shale batch sample is sealed in the batch kiln from the start until the end of the run, the process conditions for the batch are the same as the conditions that an element of oil shale would encounter in a larger continuous process kiln. For example, similar conditions of heatup rate, oxidation of the residue and cool-down prevail for the element in both systems. This batch kiln is a unit constructed in a 1987 Phase I SBIR tar sand retorting project. The kiln worked fairly well in that project; however, the need for certain modifications was observed. These modifications are now underway to simplify the operation and make the data and analysis more exact. The second quarter agenda consisted of (a) kiln modifications; (b) sample preparation; and (c) Heat Transfer calibration runs (part of proposal task number 3 -- to be completed by the end of month 7).

  13. High efficiency shale oil recovery

    SciTech Connect

    Adams, D.C.

    1993-04-22

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated on a small scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although an oil shale batch sample is sealed in the batch kiln from the start until the end of the run, the process conditions for the batch are the same as the conditions that an element of oil shale would encounter in a continuous process kiln. Similar chemical and physical conditions (heating, mixing, pyrolysis, oxidation) exist in both systems.The two most important data objectives in this phase of the project are to demonstrate (1) that the heat recovery projected for this project is reasonable and (2) that an oil shale kiln will run well and not plug up due to sticking and agglomeration. The following was completed this quarter. (1) Twelve pyrolysis runs were made on five different oil shales. All of the runs exhibited a complete absence of any plugging, tendency. Heat transfer for Green River oil shale in the rotary kiln was 84.6 Btu/hr/ft[sup 2]/[degrees]F, and this will provide for ample heat exchange in the Adams kiln. (2) One retorted residue sample was oxidized at 1000[degrees]F. Preliminary indications are that the ash of this run appears to have been completely oxidized. (3) Further minor equipment repairs and improvements were required during the course of the several runs.

  14. Leaching study of oil shale in Kentucky : with a section on Hydrologic reconnaissance of the oil shale outcrop in Kentucky

    USGS Publications Warehouse

    Leung, Samuel S.; Leist, D.W.; Davis, R.W.; Cordiviola, Steven

    1984-01-01

    Oil shales in Kentucky are rocks of predominantly Devonian age. The most prominant are the Ohio, Chattanooga, and New Albany Shales. A leaching study was done on six fresh oil shale samples and one retorted oil shale sample. Leaching reagents were distilled water, 0.0005 N sulfuric acid, and 0.05 N sulfuric acid. The concentration of constituents in the leachates were highly variable. The concentration of sodium, manganese, and zinc in the retorted shale leachate was several orders of magnitude higher than those of the leachates of fresh shale samples. The major oil shale outcrop covers approximately 1,000 square miles in a horseshoe pattern from Vanceburg, Lewis County , in the east, to Louisville, Jefferson County, in the west. The Kentucky, Red, and Licking Rivers cross the outcrop belt, the Rolling Fork River flows along the strike of the shale in the southwest part of the outcrop, and the Ohio River flows past the outcrop at the ends of the horseshoe. Oil shale does not appear to significantly alter the water quality of these streams. Oil shale is not an aquifer, but seeps and springs found in the shale indicate that water moves through it. Ground water quality is highly variable. (USGS)

  15. 3. VIEW EAST OF TAILINGS OF MERCURY RETORT. SCOOP FOR ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    3. VIEW EAST OF TAILINGS OF MERCURY RETORT. SCOOP FOR EXTRACTING MERCURY VISIBLE IN CENTER OF PHOTOGRAPH. (OCTOBER, 1995) - McCormick Group Mine, Mercury Retort, East slope of Buckskin Mountain, Paradise Valley, Humboldt County, NV

  16. Mineralogy of Antrim Shale, Michigan

    SciTech Connect

    Ruotsala, A.P.

    1980-07-31

    Semi-quantitative x-ray mineralogical determinations were made for 12 surface, 104 core, and 707 samples from oil well cuttings distributed throughout the Michigan Basin. In addition, 15 samples that had undergone retorting were checked for mineralogical changes. Gold, uranium, thorium, and rare-earth abundances were obtained for 22 samples from drill core at the Dow Chemical Company drill site in Sanilac County, Michigan. Typical Antrim Shale is composed of 50 to 60% quartz, 20 to 35% illite, 5 to 10% kaolinite, 0 to 5% chlorite, and 0 to 5% pyrite. Bedford Shale, which overlies the Antrim in eastern Michigan, has higher contents of total clays, illite, and kaolinite, and lower quartz contents. Ellsworth Shale, which grades laterally into Antrim in western Michigan, contains significant dolomite. Antrim Shale from the southern and eastern margins of the Michigan Basin contains as much as 15% kaolinite, while samples from the northern, central and western portions contain up to 5% chlorite. Illite and quartz contents tend to be highest in the deepest part of the basin, where the Antrim is thickest. Uranium content increases upward to about 40 ppM and is greatest within shales of the Antrim. Limestone interbeds contain up to about 9 ppM uranium. Highest uranium contents are found just beneath the limestone interbeds and just beneath Bedford Shale. Thorium contents, on the other hand, tend to be uniformly 10 to 12 ppM in Antrim Shale and up to 4 ppM in limestone interbeds. Gold contents range up to about 0.05 ppM in Antrim Shale and 0.01 to 0.02 ppM in limestone interbeds. Rare-earth abundances in Antrim Shale are lower than average North American shales. In the case of most rare earth elements, the overlying Bedford Shale has higher contents of most rare-earth elements.

  17. Oil shale technology. Final report

    SciTech Connect

    1995-03-01

    This collaborative project with industrial participants studied oil shale retorting through an integrated program of fundamental research, mathematical model development and operation of a 4-tonne-per-day solid recirculation oil shale test unit. Quarterly, project personnel presented progress and findings to a Project Guidance Committee consisting of company representatives and DOE program management. We successfully operated the test unit, developed the oil shale process (OSP) mathematical model, evaluated technical plans for process scale up and determined economics for a successful small scale commercial deployment, producing premium motor fuel, specility chemicals along with electricity co-production. In budget negotiations, DOE funding for this three year CRADA was terminated, 17 months prematurely, as of October 1993. Funds to restore the project and continue the partnership have not been secured.

  18. Retort process modelling for Indian traditional foods.

    PubMed

    Gokhale, S V; Lele, S S

    2014-11-01

    Indian traditional staple and snack food is typically a heterogeneous recipe that incorporates varieties of vegetables, lentils and other ingredients. Modelling the retorting process of multilayer pouch packed Indian food was achieved using lumped-parameter approach. A unified model is proposed to estimate cold point temperature. Initial process conditions, retort temperature and % solid content were the significantly affecting independent variables. A model was developed using combination of vegetable solids and water, which was then validated using four traditional Indian vegetarian products: Pulav (steamed rice with vegetables), Sambar (south Indian style curry containing mixed vegetables and lentils), Gajar Halawa (carrot based sweet product) and Upama (wheat based snack product). The predicted and experimental values of temperature profile matched with ±10 % error which is a good match considering the food was a multi component system. Thus the model will be useful as a tool to reduce number of trials required to optimize retorting of various Indian traditional vegetarian foods. PMID:26396305

  19. High efficiency shale oil recovery

    SciTech Connect

    Adams, D.C.

    1992-01-01

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated on a small scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although an oil shale batch sample is sealed in the batch kiln from the start until the end of the run, the process conditions for the batch are the same as the conditions that an element of oil shale would encounter in a continuous process kiln. Similar chemical and physical (heating, mixing) conditions exist in both systems. The two most important data objectives in this phase of the project are to demonstrate (1) that the heat recovery projected for this project is reasonable and (2) that an oil shale kiln will run well and not plug up due to sticking and agglomeration. The following was completed and is reported on this quarter: (1) A software routine was written to eliminate intermittently inaccurate temperature readings. (2) We completed the quartz sand calibration runs, resolving calibration questions from the 3rd quarter. (3) We also made low temperature retorting runs to identify the need for certain kiln modifications and kiln modifications were completed. (4) Heat Conductance data on two Pyrolysis runs were completed on two samples of Occidental oil shale.

  20. The development of an integrated multistaged fluid bed retorting process. Annual report, October 1991--September 1992

    SciTech Connect

    Carter, S.; Vego, A.; Stehn, J.; Taulbee, D.; Robl, T.; Hower, J.; Mahboub, K.; Robertson, R.; Hornsberger, P.; Oduroh, P.; Simpson, A.

    1992-12-01

    This report summarizes the progress made on the development of an integrated multistage fluidized bed retorting process (KENTORT II) during the period of October 1, 1991 through September 30, 1992. The KENTORT II process includes integral fluidized bed zones for pyrolysis (shale oil production), gasification (synthesis gas production), and combustion of the spent oil shale for process heat. The purpose of this program is to design and test the KENTORT II process at the 50-lb/hr scale. The work completed this year involved several different areas. Basic studies of the cracking and coking kinetics of shale oil vapors were carried out in fluidized and fixed bed reactors using both freshly generated shale oil vapors and model compounds. The design and fabrication of the 50-lb/hr KENTORT II reactor was completed and installation of the process components was initiated. The raw oil shale sample (Cleveland Member from Montgomery County, Kentucky) for the program was mined, prepared, characterized and stored. A preliminary study of KENTORT II-derived oil for possible paving applications was completed, and it was concluded that the shale exhibits acceptable properties as an asphalt recycling agent.

  1. Shale-oil-recovery systems incorporating ore beneficiation. Final report.

    SciTech Connect

    Weiss, M.A.; Klumpar, I.V.; Peterson, C.R.; Ring, T.A.

    1982-10-01

    This study analyzed the recovery of oil from oil shale by use of proposed systems which incorporate beneficiation of the shale ore (that is concentration of the kerogen before the oil-recovery step). The objective was to identify systems which could be more attractive than conventional surface retorting of ore. No experimental work was carried out. The systems analyzed consisted of beneficiation methods which could increase kerogen concentrations by at least four-fold. Potentially attractive low-enrichment methods such as density separation were not examined. The technical alternatives considered were bounded by the secondary crusher as input and raw shale oil as output. A sequence of ball milling, froth flotation, and retorting concentrate is not attractive for Western shales compared to conventional ore retorting; transporting the concentrate to another location for retorting reduces air emissions in the ore region but cost reduction is questionable. The high capital and energy cost s results largely from the ball milling step which is very inefficient. Major improvements in comminution seem achievable through research and such improvements, plus confirmation of other assumptions, could make high-enrichment beneficiation competitive with conventional processing. 27 figures, 23 tables.

  2. Assessment of combustion of oil shale refinery by-products in a TP-101 boiler

    NASA Astrophysics Data System (ADS)

    Sidorkin, V. T.; Tugov, A. N.; Vereshchetin, V. A.; Mel'nikov, D. A.

    2015-04-01

    The most cost-efficient method for utilization of the oil shale refinery by-products, viz., the retort gas and the shale gasoline, for power generation is combustion of these products in power-generating oil shale-fired boilers. Calculation studies carried out at the Estonian electric power plant in Narva, an enterprise of EESTI ENERGIA, have shown that recycling of the flue gases in the furnace of a TP-101 boiler enables an increase in the portion of the oil shale refinery by-products burned in the boiler from the current 7% to 40%. Recycling of the flue gases is aimed at maintaining the temperatures in the furnace at a level characteristic of combustion of oil shale and reducing the nitric oxide concentration in the retort gas burners' flame. The degree of the flue gas recycling depends on the percentage of the burnt oil shale refinery by-products in the total heat generation and increases with the increasing percentage. For the threshold value of 40% under the rated conditions, the flue gas recycling accounts for 10%. A complete changeover of the boiler to combustion of only the retort gas in place of the oil shale does not seem to be possible, since this will necessitate major modification to the TP-101 boiler heating surfaces. Considering the obtained results, as a pilot project, one boiler furnace was modified by installing six retort gas burners and a flue gas recycling system.

  3. Fractured shale reservoirs: Towards a realistic model

    SciTech Connect

    Hamilton-Smith, T.

    1996-09-01

    Fractured shale reservoirs are fundamentally unconventional, which is to say that their behavior is qualitatively different from reservoirs characterized by intergranular pore space. Attempts to analyze fractured shale reservoirs are essentially misleading. Reliance on such models can have only negative results for fractured shale oil and gas exploration and development. A realistic model of fractured shale reservoirs begins with the history of the shale as a hydrocarbon source rock. Minimum levels of both kerogen concentration and thermal maturity are required for effective hydrocarbon generation. Hydrocarbon generation results in overpressuring of the shale. At some critical level of repressuring, the shale fractures in the ambient stress field. This primary natural fracture system is fundamental to the future behavior of the fractured shale gas reservoir. The fractures facilitate primary migration of oil and gas out of the shale and into the basin. In this process, all connate water is expelled, leaving the fractured shale oil-wet and saturated with oil and gas. What fluids are eventually produced from the fractured shale depends on the consequent structural and geochemical history. As long as the shale remains hot, oil production may be obtained. (e.g. Bakken Shale, Green River Shale). If the shale is significantly cooled, mainly gas will be produced (e.g. Antrim Shale, Ohio Shale, New Albany Shale). Where secondary natural fracture systems are developed and connect the shale to aquifers or to surface recharge, the fractured shale will also produce water (e.g. Antrim Shale, Indiana New Albany Shale).

  4. OCCIDENTAL VERTICAL MODIFIED IN SITU PROCESS FOR THE RECOVERY OF OIL FROM OIL SHALE. PHASE II

    SciTech Connect

    Nelson, Reid M.

    1980-09-01

    The progress presented in this report covers the period June 1, 1980 through August 31, 1980 under the work scope for.Phase II of the DOE/Occidental Oil Shale, Inc. (OOSI) Cooperative Agreement. The major activities at OOSI 1s Logan Wash site during the quarter were: mining the voids at all levels for Retorts 7, 8 and 8x; completing Mini-Retort (MR) construction; continuing surface facility construction; tracer testing the MR 1 s; conducting Retorts 7 & 8 related Rock Fragmentation tests; setting up and debugging the Sandia B-61 trailer; and preparing the Phase II instrumentation plan.

  5. Parachute Creek shale-oil program. [Brochure

    SciTech Connect

    Not Available

    1982-01-01

    Union Oil Company has a plan for commercial shale-oil production at the Parachute Creek area of Colorado. This brochure describes the property and the company's concept for room and pillar mining and upflow retorting. Environmental precautions will preserve and restore vegetation on disturbed land and will safeguard local streams and underground basinx. Union will assist local communities to provide housing and services. 17 figures. (DCK)

  6. Potential small-scale development of western oil shale

    SciTech Connect

    Smith, V.; Renk, R.; Nordin, J.; Chatwin, T.; Harnsberger, M.; Fahy, L.J.; Cha, C.Y.; Smith, E.; Robertson, R.

    1989-10-01

    Several studies have been undertaken in an effort to determine ways to enhance development of western oil shale under current market conditions for energy resources. This study includes a review of the commercial potential of western oil shale products and byproducts, a review of retorting processes, an economic evaluation of a small-scale commercial operation, and a description of the environmental requirements of such an operation. Shale oil used as a blend in conventional asphalt appears to have the most potential for entering today's market. Based on present prices for conventional petroleum, other products from oil shale do not appear competitive at this time or will require considerable marketing to establish a position in the marketplace. Other uses for oil shale and spent shale, such as for sulfur sorbtion, power generation, cement, aggregate, and soil stabilization, are limited economically by transportation costs. The three-state area area consisting of Colorado, Utah, and Wyoming seems reasonable for the entry of shale oil-blended asphalt into the commercial market. From a review of retorting technologies and the product characteristics from various retorting processes it was determined that the direct heating Paraho and inclined fluidized-bed processes produce a high proportion of heavy material with a high nitrogen content. The two processes are complementary in that they are each best suited to processing different size ranges of materials. An economic evaluation of a 2000-b/d shale oil facility shows that the operation is potentially viable, if the price obtained for the shale oil residue is in the top range of prices projected for this product. Environmental requirements for building and operating an oil shale processing facility are concerned with permitting, control of emissions and discharges, and monitoring. 62 refs., 6 figs., 10 tabs.

  7. Enthalpy relations for Eastern oil shales

    SciTech Connect

    Camp, D.W.

    1987-11-01

    Relations were developed that allow easy and accurate calculation of enthalpy changes during the heating, retorting, or cooling of raw, spent, or burned Eastern oil shales. The heat capacities of the mineral matter, bound water, kerogen, and char, and the heat of mineral dehydration are given by linear or quadratic functions of temperature. Values are recommended for the heats of kerogen pyrolysis and pyrite decomposition. A relation was developed for estimating the extent of mineral dehydration as a function of temperature. Predictions made using these relations agree with all available Eastern shale data. 36 refs., 6 figs., 3 tabs.

  8. Western states enhanced oil shale recovery program: Shale oil production facilities conceptual design studies report

    SciTech Connect

    Not Available

    1989-08-01

    This report analyzes the economics of producing syncrude from oil shale combining underground and surface processing using Occidental's Modified-In-Situ (MIS) technology and Lawrence Livermore National Laboratory's (LLNL) Hot Recycled Solids (HRS) retort. These retorts form the basic technology employed for oil extraction from oil shale in this study. Results are presented for both Commercial and Pre-commercial programs. Also analyzed are Pre-commercialization cost of Demonstration and Pilot programs which will confirm the HRS and MIS concepts and their mechanical designs. These programs will provide experience with the circulating Fluidized Bed Combustor (CFBC), the MIS retort, the HRS retort and establish environmental control parameters. Four cases are considered: commercial size plant, demonstration size plant, demonstration size plant minimum CFBC, and a pilot size plant. Budget cost estimates and schedules are determined. Process flow schemes and basic heat and material balances are determined for the HRS system. Results consist of summaries of major equipment sizes, capital cost estimates, operating cost estimates and economic analyses. 35 figs., 35 tabs.

  9. High efficiency shale oil recovery

    SciTech Connect

    Adams, D.C.

    1992-01-01

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated at bench-scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although a batch oil shale sample will be sealed in the batch kiln from the start until the end of the run, the process conditions for the batch will be the same as the conditions that an element of oil shale would encounter in a large continuous process kiln. For example, similar conditions of heat-up rate (20 deg F/min during the pyrolysis), oxidation of the residue and cool-down will prevail for the element in both systems. This batch kiln is a unit constructed in a 1987 Phase I SBIR tar sand retorting project. The kiln worked fairly well in that project; however, the need for certain modifications was observed. These modifications are now underway to simplify the operation and make the data and analysis more exact. The agenda for the first three months of the project consisted of the first of nine tasks and was specified as the following four items: 1. Sample acquisition and equipment alteration: Obtain seven oil shale samples, of varying grade each 10 lb or more, and samples of quartz sand. Order equipment for kiln modification. 3. Set up and modify kiln for operation, including electric heaters on the ends of the kiln. 4. Connect data logger and make other repairs and changes in rotary batch kiln.

  10. Method of chemical analysis for oil shale wastes

    SciTech Connect

    Wallace, J.R.; Alden, L.; Bonomo, F.S.; Nichols, J.; Sexton, E.

    1984-06-01

    Several methods of chemical analysis are described for oil shale wastewaters and retort gases. These methods are designed to support the field testing of various pollution control systems. As such, emphasis has been placed on methods which are rapid and sufficiently rugged to perform well under field conditions. Ion chromatograph has been developed as a technique for the minor non-carbonate inorganic anions in retort water, including SO4, NO3, S2O3, SCN(-1), and total S. The method recommended for sulfide is a potiometric titration with Pb(II). The freezing point depression was used to determine the total solute content in retort waters, a test which can be considered analogous to the standard residue test. Three methods are described for the determination of total ammoniacal nitrogen in retort wastewaters: (1) a modified ion selective electrode technique, (2) an optical absorption technique, and (3) an ion chromatographic technique. Total sulfur in retort gas is determined by combusting the gas in a continuously flowing system, whereupon the resulting sulfur dioxide is determined by SO2 monitor. Individual sulfur species in retort gas including H2S, COS, SO2, and CH3CH2SH are determined by gas chromatography with flame photometric detection. Quality control, pH, conductivity, total inorganic carbon, and total organic carbon measurements are discussed briefly.

  11. Occidental vertical modified in situ process for the recovery of oil from oil shale, Phase 2. Construction, operation, testing, and environmental impact. Final report, August 1981-December 1982. Volume 1

    SciTech Connect

    Stevens, A.L.; Zahradnik, R.L.; Kaleel, R.J.

    1984-01-01

    Occidential Oil Shale, Inc. (OOSI) recently completed the demonstration of mining, rubblization, ignition, and simulataneous processing of two commericalized modified in situ (MIS) retorts at the Logas Wash facility near DeBeque, Colorado. Upon completion of Retort 6 in 1978, Occidential began incorporating all of the knowledge previously acquired in an effort to design two more commercial-sized MIS retorts. Any commercial venture of the future would require the ability to operate simultaneously more than one retort. Thus, Retorts 7 and 8 were developed during 1980 and 1981 through joint funding of the DOE and OOSI in Phase II. Rubblization of the retorts produced an average rubble void of 18.5% in the low grade shale (17 gallons per ton) at the Logan Wash site. After rubblization, bulkheads were constructed, inlet and offgas pipes were installed and connected to surface processing facilities and liquid product handling systems were connected to the retorts. Extensive instrumentation was installed in cooperation with Sandia National Laboratories for monitoring the complete operation of the retorts. After pre-ignition testing, Retort 8 was ignited in December of 1981 and Retort 7 was ignited in January of 1982. The retorts were operated without interruption from ignition until mid- November of 1982 at which time inlet gas injection was terminated and water quenching was begun. Total product yield from the two retorts was approximately 200,000 barrels of oil, or 70% of the Fischer Assay oil-in-place in the rubblized rock in the two retrots. Water quenching studies were conducted over a period of several months, with the objective of determining the rate of heat extraction from the retorts as well as determining the quantity and quality of offgas and water coming out from the quenching process. Data from these studies are also included in this Summary Report. 62 figs., 18 tabs.

  12. BX in situ oil shale project. Final report

    SciTech Connect

    Dougan, P.M.

    1983-09-01

    The objective of the Project was to demonstrate the technical feasibility of using superheated steam as a heat-carrying medium to retort in situ the oil shale in the Green River Formation leached zone and provide a mechanism for the recovery of the retorted shale oil with a minimum impact on the environment. Utilizing primarily the natural porosity in the leached zone, approximately 450 billion Btu's of heat have been injected into injection wells at the project site over a 2-year period in an attempt to heat to retorting temperatures in a shale zone approximately 540 feet thick and covering about one acre. The field Project is located at Equity's BX In Situ site in Rio Blanco County in northwestern Colorado. This final report summarizes the field and laboratory work conducted as the BX In Situ Oil Shale Project, a project jointly funded by the US Department of Energy Equity Oil Company under a Cooperative Agreement entered into on March 1, 1977. The September 15, 1982, and includes a period of two years from September 18, 1979 to September 15, 1982, during which superheated steam and hot water were injected into an array of eight injection wells completed in the leached zone oil shale of the Parachute Creek member of the Green River Formation in the Piceance Creek Basin of northwestern Colorado. (20 figures, 21 tables)

  13. Explosively produced fracture of oil shale. Progress report, October-December 1980

    SciTech Connect

    Sinoradzki, H.M.

    1981-07-01

    A major technological limit on the in situ retorting of oil shale is the effective rubbling of the rock. Consequently, efficient and economical recovery of oil from shale is dependent directly on developing a more sophisticated blasting technology. Crucial to this technology is understanding the behavior of the explosive. Calculations of pressures and shock-front positions are developed and compared graphically to the aquarium-test experimental data for two different diameter explosive configurations for ammonium nitrate/fuel oil (ANFO). Once the explosive reaction is understood, analytical and computational methods can be developed to simulate the blasting of the rock. Such computer modeling will allow the phenomenology of blasting to be studied and will eliminate the need for many expensive field tests. The basis for using predictive modeling and its application to predict rock fracturing is explained, and comparisons of calculations to field experimental data are presented. Also discussed is the theory of effective-elastic-moduli reduction in a transversely isotropic material containing penny-shaped cracks. It is applied to the bedded crack model in which all cracks are in the horizontal (bedding) plane of the material, as they are in oil shale. The technique equates the total body strain to the sum of the straining of the material matrix and the additional strain caused by the opening and shearing of cracks. Finally, the permeability of explosively fractured oil shale is related to the statistical distribution of cracks in the rock and their instability as stress levels increase. An expression for the specific permeability of oil shale under high stresses is derived. 22 figures.

  14. Union Oil Company of California's Parachute Creek Shale Oil Program

    SciTech Connect

    Randle, A.C.

    1982-01-01

    Union Oil Company is confident that with the completion of its project now under construction, the commercial production of oil from shale will finally become a reality. The retorting technology developed by Union scientists through 35 years of research will be proven on a commercial scale. Not only does Union Oil have confidence in its technology, but already other companies have licensed the Unishale B for their own shale projects. While shale oil will not solve all of the nation's energy problems, it will make a significant contribution to the solution.

  15. Review of rare earth element concentrations in oil shales of the Eocene Green River Formation

    USGS Publications Warehouse

    Birdwell, Justin E.

    2012-01-01

    Concentrations of the lanthanide series or rare earth elements and yttrium were determined for lacustrine oil shale samples from the Eocene Green River Formation in the Piceance Basin of Colorado and the Uinta Basin of Utah. Unprocessed oil shale, post-pyrolysis (spent) shale, and leached shale samples were examined to determine if oil-shale processing to generate oil or the remediation of retorted shale affects rare earth element concentrations. Results for unprocessed Green River oil shale samples were compared to data published in the literature on reference materials, such as chondritic meteorites, the North American shale composite, marine oil shale samples from two sites in northern Tibet, and mined rare earth element ores from the United States and China. The Green River oil shales had lower rare earth element concentrations (66.3 to 141.3 micrograms per gram, μg g-1) than are typical of material in the upper crust (approximately 170 μg g-1) and were also lower in rare earth elements relative to the North American shale composite (approximately 165 μg g-1). Adjusting for dilution of rare earth elements by organic matter does not account for the total difference between the oil shales and other crustal rocks. Europium anomalies for Green River oil shales from the Piceance Basin were slightly lower than those reported for the North American shale composite and upper crust. When compared to ores currently mined for rare earth elements, the concentrations in Green River oil shales are several orders of magnitude lower. Retorting Green River oil shales led to a slight enrichment of rare earth elements due to removal of organic matter. When concentrations in spent and leached samples were normalized to an original rock basis, concentrations were comparable to those of the raw shale, indicating that rare earth elements are conserved in processed oil shales.

  16. Chemical composition of shale oil. 1; Dependence on oil shale origin

    SciTech Connect

    Kesavan, S.; Lee, S. ); Polasky, M.E. )

    1991-01-01

    This paper reports on shale oils obtained by nitrogen retorting of North Carolina, Cleveland, Ohio, Colorado, Rundle, Stuart, and Condor oil shales that have been chemically characterized by g.c.-m.s. techniques. After species identification, chemical compositions of the shale oils have been related to the geological origins of the parent shales. Based on the characteristics observed in the chromatograms, eight semi-quantitative parameters have been used to describe the chromatograms. Six of these parameters describe the chromatograms. Six of these parameters describe the relative abundance and distribution of straight chain alkanes and alkenes in the chromatograms. The other two parameters represent the abundance, relative to the total amount of volatiles in the oil, of alkylbenzenes and alkylphenols.

  17. Improved retort for cleaning metal powders with hydrogen

    NASA Technical Reports Server (NTRS)

    Arias, A.

    1969-01-01

    Improved cleaning retort produces uniform temperature distribution in the heated zone and minimizes hydrogen channeling through the powder bed. Retort can be used for nonmetallic powders, sintering in a reducing atmosphere, and for cleaning powders in reduction atmospheres other than hydrogen.

  18. Trace elements in oil shale. Progress report, 1979-1980

    SciTech Connect

    Chappell, W R

    1980-01-01

    The purpose of this research program is to understand the potential impact of an oil shale industry on environmental levels of trace contaminants in the region. The program involves a comprehensive study of the sources, release mechanisms, transport, fate, and effects of toxic trace chemicals, principally the trace elements, in an oil shale industry. The overall objective of the program is to evaluate the environmental and health consequences of the release of toxic trace elements by shale and oil production and use. The baseline geochemical survey shows that stable trace elements maps can be constructed for numerous elements and that the trends observed are related to geologic and climatic factors. Shale retorted by above-ground processes tends to be very homogeneous (both in space and in time) in trace element content. Leachate studies show that significant amounts of B, F, and Mo are released from retorted shales and while B and Mo are rapidly flushed out, F is not. On the other hand, As, Se, and most other trace elements are not present in significant quantities. Significant amounts of F and B are also found in leachates of raw shales. Very large concentrations of reduced sulfur species are found in leachates of processed shale. Very high levels of B and Mo are taken up in some plants growing on processed shale with and without soil cover. There is a tendency for some trace elements to associate with specific organic fractions, indicating that organic chelation or complexation may play an important role. Many of the so-called standard methods for analyzing trace elements in oil shale-related materials are inadequate. A sampling manual is being written for the environmental scientist and practicing engineer. A new combination of methods is developed for separating the minerals in oil shale into different density fractions. Microbial investigations have tentatively identified the existence of thiobacilli in oil shale materials such as leachates. (DC)

  19. Characterization of Rio Blanco retort 1 water following treatment by lime-soda softening and reverse osmosis

    SciTech Connect

    Kocornik, D.J.

    1985-12-01

    Laboratory research was initiated to evaluate the chemical, physical, and toxicological characteristics of treated and untreated Rio Blanco oil shale retort water. Wet chemical analyses, metals analyses, MICROTOX assays and particle-size analysis were performed on the wastewater before and after treatment by lime-soda softening and reverse osmosis. The reverse osmosis system successfully removed dissolved solids and organics from the wastewater. Based on MICROTOX tests, the water was much less toxic after treatment by reverse osmosis. 8 refs., 7 figs., 8 tabs.

  20. Identification of data gaps found during the development of a zero-order model for a fluidized-bed retort/combustion process

    SciTech Connect

    Ammer, J.R.

    1986-01-01

    This technical note (TN) reports on the development of a zero-order ASPEN (Advanced System for Process Engineering) model for the fluidized-bed retort/combustion of an eastern oil shale. The objective of the work described was to identify data needs and to create a structure for future, more definitive models. New Albany shale was the initial reference eastern shale at the Department of Energy (DOE)/Morgantown Energy Technology Center (METC). A literature search on this shale was conducted to find the physical property data required for the ASPEN model. This TN discusses the types of missing or incomplete data, the process being modeled, and how process variables are affected by varying input parameters. The TN also presents recommendations for increasing the reliability of the simulation. 12 refs., 3 figs., 5 tabs.

  1. Effect of Narrow Cut Oil Shale Distillates on HCCI Engine Performance

    SciTech Connect

    Eaton, Scott J; Bunting, Bruce G; Lewis Sr, Samuel Arthur; Fairbridge, Craig

    2009-01-01

    In this investigation, oil shale crude obtained from the Green River Formation in Colorado using Paraho Direct retorting was mildly hydrotreated and distilled to produce 7 narrow boiling point fuels of equal volumes. The resulting derived cetane numbers ranged between 38.3 and 43.9. Fuel chemistry and bulk properties strongly correlated with boiling point.

  2. Double Retort System for Materials Compatibility Testing

    SciTech Connect

    V. Munne; EV Carelli

    2006-02-23

    With Naval Reactors (NR) approval of the Naval Reactors Prime Contractor Team (NRPCT) recommendation to develop a gas cooled reactor directly coupled to a Brayton power conversion system as the Space Nuclear Power Plant (SNPP) for Project Prometheus (References a and b) there was a need to investigate compatibility between the various materials to be used throughout the SNPP. Of particular interest was the transport of interstitial impurities from the nickel-base superalloys, which were leading candidates for most of the piping and turbine components to the refractory metal alloys planned for use in the reactor core. This kind of contamination has the potential to affect the lifetime of the core materials. This letter provides technical information regarding the assembly and operation of a double retort materials compatibility testing system and initial experimental results. The use of a double retort system to test materials compatibility through the transfer of impurities from a source to a sink material is described here. The system has independent temperature control for both materials and is far less complex than closed loops. The system is described in detail and the results of three experiments are presented.

  3. Studies of the Scottish oil shale industry. Final report. Volume 2. Shale workers' pneumoconiosis and skin conditions: epidemiological surveys of surviving ex-shale workers

    SciTech Connect

    Louw, S.J.; Cowie, H.; Seaton, A.

    1985-03-01

    This report (in 3 volumes) describes the now defunct Scottish oil shale industry and its effects on the health of its workers. This volume investigates the prevalence of skin disease and pneumoconiosis in Scottish ex-oil shale workers. A cross sectional epidemiological survey has been carried base on a population enrolled in the 1950 Scottish Oils Ltd Provident Fund. Investigation of the Fund indicated that it would have included almost all industrial workers employed in the oil shale industry between 1950 and its closure in 1962. It is concluded that workers in the Scottish shale oil industry in its latter years were not at excess risk of skin disease, perhaps because of steps taken within the industry to reduce the known hazards of dermatitis and skin cancer. However, pneumoconiosis was a definite hazard of miners and retort workers and its presence was associated with an impairment of lung function suggestive of fibrosis and possibly emphysema as well. It is suggested that prevention of this hazard might sensibly be based on the strategy used in the coalmining industry and, in the absence of further information on dust and fume exposures of shale workers, standards as applied in coalmining should be appropriate. Radiological surveillance of dust-exposed workers, whether in mines or at retorts or tips, is recommended. 39 refs., 10 figs., 48 tabs.

  4. Comparative dermotoxicity of shale oils

    SciTech Connect

    Holland, L.M.; Wilson, J.S.; Foreman, M.E.

    1980-01-01

    When shale oils are applied at higher dose levels the standard observation of tumor production and latency are often obscured by a severe inflammatory response leading to epidermal degeneration. The two experiments reported here are still in progress, however the interim results are useful in assessing both the phlogistic and tumorigenic properties of three shale oils. Three shale oils were tested in these experiments. The first crude oil (OCSO No. 6) was produced in a modified in situ report at Occidental Oil Company's Logan Wash site near Debeque, Colorado. The second crude oil (PCSO II) was produced in the above ground Paraho vertical-kiln retort located at Anvil Points near Rifle, Colorado and the third oil was the hydrotreated daughter product of the Paraho crude (PCSO-UP). Experiment I was designed to determine the highest dose level at which tumor latency could be measured without interference from epidermal degeneration. Experiment II was designed to determine the effect of application frequency on both tumor response and inflammatory phenomena. Complete epidermal degeneration was used as the only measure of severe inflammation. Relative tumorigenicity was based on the number of tumor bearing mice without regard to multiple tumors on individual animals. In both experiments, tumor occurrence was confirmed one week after initial appearance. The sex-related difference in inflammatory response is striking and certanly has significance for experimental design. An increased phlogistic sensitivity expressed in male mice could affect the meaning of an experiment where only one sex was used.

  5. Lithology, stress or pressure control of the seismicity in shale? Insights from a controlled experiment of fluid-induced fault reactivation

    NASA Astrophysics Data System (ADS)

    Rivet, D.; De Barros, L.; Daniel, G.; Guglielmi, Y.; Castilla, R.

    2015-12-01

    Shale materials are important components in petroleum systems (e.g. sealing and source rocks) and play an important role in earthquake faults. However, their mechanical behavior is still poorly understood, as it can vary from plastic to brittle. The role of fluid pressure in seismicity triggering is also not fully understood. A unique, decametric scale experiment, which aims at reactivating a natural fault by high pressure injection, was performed in shale. The injection interval was surrounded by a dense monitoring network of pressure, deformation and seismic sensors, in a well-characterized geological setting. 37 seismic events, with very small magnitude (about -4) were recorded during five series of injections within the fault zone. The spatio-temporal distribution of these events, compared with the measured displacement at the injection points, shows that most of the induced deformation is aseismic. The locations of the microseismic events are strongly asymmetrical, with most events distributed East of the fault and South of the injection area. Focal mechanisms are predominantly consistent with shear slip on a family of calcified fractures. The shale mineralogy appears to be a critical parameter governing the seismogenic character of deformation, as only calcified structures slipped seismically. As no seismic event occurs in the close vicinity of the injection, high-fluid content seems to inhibit seismic slip. Consequently, stress changes induced by this highly-pressurized volume should more likely influence the spatial distribution of seismicity. Finally, the main fault, acting as a fluid flow and/or stress barrier, strongly modifies the stress transfer. From the monitoring point of view, this experiment reflects the difficulty in quantitatively following fluid propagation in a shale formation, as seismicity will be strongly influenced by the presence of calcified fractures and by the interaction between stress transfer and lithological heterogeneities.

  6. Spatial and stratigraphic distribution of water in oil shale of the Green River Formation using Fischer assay, Piceance Basin, northwestern Colorado

    USGS Publications Warehouse

    Johnson, Ronald C.; Mercier, Tracey J.; Brownfield, Michael E.

    2014-01-01

    The spatial and stratigraphic distribution of water in oil shale of the Eocene Green River Formation in the Piceance Basin of northwestern Colorado was studied in detail using some 321,000 Fischer assay analyses in the U.S. Geological Survey oil-shale database. The oil-shale section was subdivided into 17 roughly time-stratigraphic intervals, and the distribution of water in each interval was assessed separately. This study was conducted in part to determine whether water produced during retorting of oil shale could provide a significant amount of the water needed for an oil-shale industry. Recent estimates of water requirements vary from 1 to 10 barrels of water per barrel of oil produced, depending on the type of retort process used. Sources of water in Green River oil shale include (1) free water within clay minerals; (2) water from the hydrated minerals nahcolite (NaHCO3), dawsonite (NaAl(OH)2CO3), and analcime (NaAlSi2O6.H20); and (3) minor water produced from the breakdown of organic matter in oil shale during retorting. The amounts represented by each of these sources vary both stratigraphically and areally within the basin. Clay is the most important source of water in the lower part of the oil-shale interval and in many basin-margin areas. Nahcolite and dawsonite are the dominant sources of water in the oil-shale and saline-mineral depocenter, and analcime is important in the upper part of the formation. Organic matter does not appear to be a major source of water. The ratio of water to oil generated with retorting is significantly less than 1:1 for most areas of the basin and for most stratigraphic intervals; thus water within oil shale can provide only a fraction of the water needed for an oil-shale industry.

  7. Spatial and stratigraphic distribution of water in oil shale of the Green River Formation using Fischer Assay, Piceance Basin, northwestern Colorado

    USGS Publications Warehouse

    Johnson, Ronald C.; Mercier, Tracey J.; Brownfield, Michael E.

    2014-01-01

    The spatial and stratigraphic distribution of water in oil shale of the Eocene Green River Formation in the Piceance Basin of northwestern Colorado was studied in detail using some 321,000 Fischer assay analyses in the U.S. Geological Survey oil-shale database. The oil-shale section was subdivided into 17 roughly time-stratigraphic intervals, and the distribution of water in each interval was assessed separately. This study was conducted in part to determine whether water produced during retorting of oil shale could provide a significant amount of the water needed for an oil-shale industry. Recent estimates of water requirements vary from 1 to 10 barrels of water per barrel of oil produced, depending on the type of retort process used. Sources of water in Green River oil shale include (1) free water within clay minerals; (2) water from the hydrated minerals nahcolite (NaHCO3), dawsonite (NaAl(OH)2CO3), and analcime (NaAlSi2O6.H20); and (3) minor water produced from the breakdown of organic matter in oil shale during retorting. The amounts represented by each of these sources vary both stratigraphically and areally within the basin. Clay is the most important source of water in the lower part of the oil-shale interval and in many basin-margin areas. Nahcolite and dawsonite are the dominant sources of water in the oil-shale and saline-mineral depocenter, and analcime is important in the upper part of the formation. Organic matter does not appear to be a major source of water. The ratio of water to oil generated with retorting is significantly less than 1:1 for most areas of the basin and for most stratigraphic intervals; thus water within oil shale can provide only a fraction of the water needed for an oil-shale industry.

  8. Development of an induced fracture model for Antrim shale

    SciTech Connect

    Carmi, S.

    1980-08-01

    The main goal of our investigation was to develop a structural response model which simulates the in-situ fracturing of Antrim oil shale for the purpose of enhancing permeability and thus allow partial combustion for the subsequent retorting and recovery of petroleum products. We strictly adhered to our goal and developed a model, which through a number of stages, is capable of predicting the change in rock permeability for a given explosive load and existing in-situ conditions such as rock material properties and overburden pressure. Our computer model uses as a first step a finite element package which we developed for calculating the induced stress field due to the explosion. This stage is followed by a rock-failure and crack analysis of the individual elements and joints which culminates in the final state which is the rock permeability assessment. Our results are presented as computer program listings, graphic representations of the finite element mesh and figures which graphically display our findings. The result relating to the differential permeability penetration, namely the preferred vertical rather than the horizontal direction, is noteworthy and of particular practical interest.

  9. Influence of frequency, grade, moisture and temperature on Green River oil shale dielectric properties and electromagnetic heating processes

    SciTech Connect

    Hakala, J. Alexandra; Stanchina, William; Soong, Yee; Hedges, Sheila

    2011-01-01

    Development of in situ electromagnetic (EM) retorting technologies and design of specific EM well logging tools requires an understanding of various process parameters (applied frequency, mineral phases present, water content, organic content and temperature) on oil shale dielectric properties. In this literature review on oil shale dielectric properties, we found that at low temperatures (<200° C) and constant oil shale grade, both the relative dielectric constant (ε') and imaginary permittivity (ε'') decrease with increased frequency and remain constant at higher frequencies. At low temperature and constant frequency, ε' decreases or remains constant with oil shale grade, while ε'' increases or shows no trend with oil shale grade. At higher temperatures (>200º C) and constant frequency, epsilon' generally increases with temperature regardless of grade while ε'' fluctuates. At these temperatures, maximum values for both ε' and ε'' differ based upon oil shale grade. Formation fluids, mineral-bound water, and oil shale varve geometry also affect measured dielectric properties. This review presents and synthesizes prior work on the influence of applied frequency, oil shale grade, water, and temperature on the dielectric properties of oil shales that can aid in the future development of frequency- and temperature-specific in situ retorting technologies and oil shale grade assay tools.

  10. Summary of the oil shale fragmentation program at Anvil Points Mine, Colorado

    SciTech Connect

    Dick, R.D.; Young, C.; Fourney, W.L.

    1984-01-01

    During 1981 and 1982, an extensive oil shale fragmentation research program was conducted at the Anvil Points Mine near Rifle, Colorado. The primary goals were to investigate factors involved for adequate fragmentation of oil shale and to evaluate the feasibility of using the modified in situ retort (MIS) method for recovery of oil from oil shale. The test program included single-deck, single-borehole tests to obtain basic fragmentation data; multiple-borehole, multiple-deck explosive tests to evaluate practical aspects for developing an in situ retort; and the development of a variety of instrumentation techniques to diagnose the blasting event. This paper will present an outline of the field program, the type of instrumentation used, some typical results from the instrumentation, and a discussion of explosive engineering problems encountered over the course of the program. 4 references, 21 figures, 1 table.

  11. Studies of the Scottish oil shale industry. Volume 3. Causes of death of Scottish oil shale workers. Final report

    SciTech Connect

    Miller, B.G.; Cowie, H.; Middleton, W.G.; Seaton, A.

    1985-05-01

    The hazards of the Scottish oil shale industry are reported in three volumes. This volume addresses the cause of death for personnel in the oil shale industry. Skin cancer deaths showed a hazard significantly greater than unity. In comparing oil shale workers mortality with that of the population of 2 counties, an increase in death from bronchitis and emphysema was demonstrated. Comparisons of mortality within the study group to determine if any particular jobs in the industry were more hazardous than others showed no significant associations. There appeared to be a slight excess of prostrate cancer among retort workers. In a case-control study, no significant increase in relative hazard of lung cancer was found in association with workers or residents in areas of high shale activity. 21 refs., 4 figs., 27 tabs. (DMC)

  12. CO2 Sequestration within Spent Oil Shale

    NASA Astrophysics Data System (ADS)

    Foster, H.; Worrall, F.; Gluyas, J.; Morgan, C.; Fraser, J.

    2013-12-01

    Worldwide deposits of oil shales are thought to represent ~3 trillion barrels of oil. Jordanian oil shale deposits are extensive and of high quality, and could represent 100 billion barrels of oil, leading to much interest and activity in the development of these deposits. The exploitation of oil shales has raised a number of environmental concerns including: land use, waste disposal, water consumption, and greenhouse gas emissions. The dry retorting of oil shales can overcome a number of the environmental impacts, but this leaves concerns over management of spent oil shale and CO2 production. In this study we propose that the spent oil shale can be used to sequester CO2 from the retorting process. Here we show that by conducting experiments using high pressure reaction facilities, we can achieve successful carbonation of spent oil shale. High pressure reactor facilities in the Department of Earth Sciences, Durham University, are capable of reacting solids with a range of fluids up to 15 MPa and 350°C, being specially designed for research with supercritical fluids. Jordanian spent oil shale was reacted with high pressure CO2 in order to assess whether there is potential for sequestration. Fresh and reacted materials were then examined by: Inductively Coupled Plasma Mass Spectrometry (ICP-MS), Thermogravimetric Analysis (TGA), X-Ray Fluorescence (XRF) and X-Ray Diffraction (XRD) methods. Jordanian spent oil shale was found to sequester up to 5.8 wt % CO2, on reacting under supercritical conditions, which is 90% of the theoretical carbonation. Jordanian spent oil shale is composed of a large proportion of CaCO3, which on retorting decomposes, forming CaSO4 and Ca-oxides which are the focus of carbonation reactions. A factorially designed experiment was used to test different factors on the extent of carbonation, including: pressure; temperature; duration; and the water content. Analysis of Variance (ANOVA) techniques were then used to determine the significance of

  13. Gas shale/oil shale

    USGS Publications Warehouse

    Fishman, N.S.; Bereskin, S.R.; Bowker, K.A.; Cardott, B.J.; Chidsey, T.C.; Dubiel, R.F.; Enomoto, C.B.; Harrison, W.B.; Jarvie, D.M.; Jenkins, C.L.; LeFever, J.A.; Li, Peng; McCracken, J.N.; Morgan, C.D.; Nordeng, S.H.; Nyahay, R.E.; Schamel, Steven; Sumner, R.L.; Wray, L.L.

    2011-01-01

    This report provides information about specific shales across North America and Europe from which gas (biogenic or thermogenic), oil, or natural gas liquids are produced or is actively being explored. The intent is to re?ect the recently expanded mission of the Energy Minerals Division (EMD) Gas Shales Committee to serve as a single point of access to technical information on shales regardless of the type of hydrocarbon produced from them. The contents of this report were drawn largely from contributions by numerous members of the EMD Gas Shales Advisory Committee, with much of the data being available from public websites such as state or provincial geological surveys or other public institutions. Shales from which gas or oil is being produced in the United States are listed in alphabetical order by shale name. Information for Canada is presented by province, whereas for Europe, it is presented by country.

  14. Kinetics of oil shale char gasification

    SciTech Connect

    Thomson, W.J.; Gerber, M.A.; Hatter, M.M.; Oakes, D.G.

    1980-01-01

    Experimental work on gasification of oil shale char with CO/sub 2/ and steam are presented in this report. All of the gasification experiments were conducted with the same apparatus employed in the earlier oxidation work. As before, powdered shale samples (200 mesh) of previously retorted oil shale from the Parachute Creek member in Colorado were suspended from an electrobalance and placed in a furnace. In this way continuous gravimetric readings were available to monitor the consumption of the char. The off-gases were analyzed on a Carle gas chromatograph equipped with a Carbosieve B column. The retorted raw shale assayed at 50 GPT and was exposed to CO/sub 2/ pressures as high as 100 KPa and H/sub 2/O pressures as high as 75 KP/sub a/. Because there was evidence of the water gas shift reaction during steam gasification, separate experiments were also conducted in order to determine the rate of this reaction as a function of temperature and concentration of the reactant gases. The Livermore results predicted char consumption rates which were much higher than those observed for mixed gasification runs with P/sub CO/sub 2// > 10 KPa. The kinetic results from this work gave reasonable matches to the data at P/sub CO/sub 2// < 15 KPa but also predicted much higher rates at CO/sub 2/ pressures greater than 20 KPa. The data exhibit a much lower char consumption rate than predicted. Also shown in this figure are the predictions assuming that only CO/sub 2/ gasification takes place. The assumption provides a reasonable match to the experimental data and suggests that the presence of CO/sub 2/ is somehow inhibiting steam gasification.

  15. BX in situ oil shale project

    SciTech Connect

    Dougan, P.M.; Dockter, L.

    1981-01-01

    The BX In Situ Oil Shale Project, jointly sponsored by Equity Oil Company and the U.S. Department of Energy, has been in operation continuously since September 18, 1979. Between that time and February 28, 1981, 625,300 barrels (99,400 m/sup 3/) of water as steam have been injected into eight Project injection wells at an average wellhead temperature of 605 /degree/F. (318 /degree/C.) and an average wellhead pressure of 1,314 psig (9,053 kPa). During the same period, 524,500 barrels (83,400 m/sup 3/) of fluid have been produced from five Project production wells. Steam injection has resulted in heating of the ''leached zone '' of the Parachute Creek Member of the Green River formation and this in turn has resulted in the in situ retorting of a portion of the oil shale of the ''leached zone '' and the recovery of a measurable amount of oil resulting from this retorting. 4 refs.

  16. Beneficiation and hydroretorting of low grade oil shale

    SciTech Connect

    Tippin, R.B.; Hanna, J.; Janka, J.C.; Rex, R.C. Jr.

    1985-02-01

    A new approach to oil recovery from low grade oil shales has been developed jointly by the Mineral Resources Institute (MRI) of The University of Alabama and the HYCRUDE Corporation. The approach is based on the HYTORT process, which utilized hydrogen gas during the retorting process to enhance oil yields from many types of oil shales. The performance of the HYTORT process is further improved by combining it with MRI's froth flotation process. Taking advantage of differences in the surface properties of the kerogen and the inorganic mineral constituents of the oil shales, the MRI process can reject up to three quarters by weight of relatively kerogen-free inorganic fractions of the oil shale before HYTORT processing. The HYTORT and MRI processes are discussed. Results of tests by each process on oil shales of low to moderate inherent kerogen content are presented. Also discussed are the results of the combined processes on an Indiana New Albany oil shale. By combining the two processes, the raw shale which yielded 12 gallons of oil per ton by Fischer Assay was upgraded by flotation to a product yielding 27 gallons of Fischer Assay oil per ton. HYTORT processing of the beneficiated product recovered 54 gallons of oil per ton, an improvement in oil yield by a factor of 4.5 over the raw shale Fischer Assay.

  17. Improved mechanical properties of retorted carrots by ultrasonic pre-treatments.

    PubMed

    Day, Li; Xu, Mi; Øiseth, Sofia K; Mawson, Raymond

    2012-05-01

    The use of ultrasound pre-processing treatment, compared to blanching, to enhance mechanical properties of non-starchy cell wall materials was investigated using carrot as an example. The mechanical properties of carrot tissues were measured by compression and tensile testing after the pre-processing treatment prior to and after retorting. Carrot samples ultrasound treated for 10 min at 60 °C provided a higher mechanical strength (P<0.05) to the cell wall structure than blanching for the same time period. With the addition of 0.5% CaCl(2) in the pre-treatment solution, both blanching and ultrasound treatment showed synergistic effect on enhancing the mechanical properties of retorted carrot pieces. At a relatively short treatment time (10 min at 60 °C) with the use of 0.5% CaCl(2), ultrasound treatment achieved similar enhancement to the mechanical strength of retorted carrots to blanching for a much longer time period (i.e. 40 min). The mechanism involved appears to be related to the stress responses present in all living plant matter. However, there is a need to clarify the relative importance of the potential stress mechanisms in order to get a better understanding of the processing conditions likely to be most effective. The amount of ultrasound treatment required is likely to involve low treatment intensities and there are indications from the structural characterisation and mechanical property analyses that the plant cell wall tissues were more elastic than that accomplished using low temperature long time blanching.

  18. DOE oil shale reference sample bank: Quarterly report, July-September 1987

    SciTech Connect

    Owen, L.B.

    1987-09-01

    The DOE Oil Shale Program was restructured in FY84 to implement a 5-year period of basic and applied research in the study of the phenomena involved in oil shale pyrolysis/retorting. The program calls for the study of two reference shales per year for a period of 5 years. Consequently, the program calls for the identification, acquisition, processing, characterization, storage, disbursement, and record keeping for ten reference shales in a period of 5 years. Two FY86 and one FY87 reference shales have been acquired, processed and stored under inert gas. The Eastern shale, designated E86, was obtained from the Clegg Creek Member of the New Albany Shale at a quarry near Louisville, Kentucky in the first quarter of FY86. The FY86 Western Shale was obtained from the Exxon Colony Mine, located near Parachute, Colorado, during the first quarter of FY86. The FY87 Western Shale was obtained from the Tipton Member of the Green River Formation near Rock Springs, Wyoming during the fourth quarter of FY87. Partial distributions of the FY86 shale have been made to DOE and non-DOE contractors. Complete descriptions of the FY87 Western reference shale locale, shale processing procedures and analytical characterization are provided in this report. 7 refs., 6 figs., 1 tab.

  19. Devonian shale

    SciTech Connect

    Not Available

    1980-01-01

    Objectives were to: estimate the in-place gas resource of Devonian Shale in the eastern United States, project possible production volumes and reserve additions of recoverable gas at various price levels with current technology, estimate the potential of new technology and its effect on production and reserve additions, examine constraints of Devonian Shale development, and compare findings with other published studies.

  20. Early jointing in coal and black shale: Evidence for an Appalachian-wide stress field as a prelude to the Alleghanian orogeny

    SciTech Connect

    Engelder, T.; Whitaker, A.

    2006-07-15

    Early ENE-striking joints (present coordinates) within both Pennsylvanian coal and Devonian black shale of the Central and Southern Appalachians reflect an approximately rectilinear stress field with a dimension > 1500 km. This Appalachian-wide stress field (AWSF) dates from the time of joint propagation, when both the coal and shale were buried to the oil window during the 10-15 m.y. period straddling the Pennsylvanian-Permian boundary. The AWSF was generated during the final assembly of Pangea as a consequence of plate-boundary tractions arising from late-stage oblique convergence, where maximum horizontal stress, S-H, of the AWSF was parallel to the direction of closure between Gondwana and Laurentia. After closure, the AWSF persisted during dextral slip of peri-Gondwanan microcontinents, when SH appears to have crosscut plate-scale trans-current faults at around 30{sup o}. Following > 10 m.y. of dextral slip during tightening of Gondwana against Laurentia, the AWSF was disrupted by local stress fields associated with thrusting on master basement decollements to produce the local orocline-shaped Alleghanian map pattern seen today.

  1. Oil and gas yields from devonian oil shale in the 50-lb/hr KENTORT II process demonstration unit: Initial results

    SciTech Connect

    Robl, R.L.; Carter, S.D.; Taulbee, D.N.

    1993-12-31

    The broad objective of this program is to perform the research necessary to design, construct, test, and optimize the KENTORT II process at the 50-lb/hr scale. Many of our objectives have already been realized. The retort has been successfully constructed and the shakedown phase is essentially complete. In addition, much of the coking and cracking kinetics experiments have been completed which will provide important information for the operation of the retort. We are now entering the testing phase for the retort which has the following objectives: Determine any relationships between the retorting conditions and the yield and characteristics of the products, and compare the results to those from the bench-scale shale oil cracking and coking experiments; study and develop alternative applications for the products from the KENTORT II process. In particular, asphalt performance tests will be conducted on the heavy fraction of oil produced during the testing phase.

  2. Hydrologic-information needs for oil-shale development, northwestern Colorado

    USGS Publications Warehouse

    Taylor, O.J.

    1982-01-01

    Hydrologic information is not adequate for proper development of the large oil-shale reserves of Piceance basin in northwestern Colorado. Exploratory drilling and aquifer testing are needed to define the hydrologic system, to provide wells for aquifer testing, to design mine-drainage techniques, and to explore for additional water supplies. Sampling networks are needed to supply hydrologic data on the quantity and quality of surface water, ground water, and springs. A detailed sampling network is proposed for the White River basin because of expected impacts related to water supplies and waste disposal. Emissions from oil-shale retorts to the atmosphere need additional study because of possible resulting corrosion problems and the destruction of fisheries. Studies of the leachate materials and the stability of disposed retorted shale piles are needed to insure that these materials will not cause problems. Hazards related to in-situ retorts, and the wastes related to oil-shale development in general also need further investigation. (USGS)

  3. The effect of mineral species on oil shale char combustion

    SciTech Connect

    Cavalieri, R.P.; Thompson, W.J.

    1983-02-01

    In order to increase the energy efficiency of above-ground oil shale processes, the carbonaceous residue (''char'') remaining on retorted oil shale (''spent'' shale) will either be combusted or gasified. Although there is no great difficulty in combusting the char, it is important that combustion be carried out in a controlled fashion. Failure to do so can result in high temperatures (>900/sup 0/K) and the decomposition of mineral carbonates. These decomposition reactions are not only endothermic but some of the products have the potential to cause environmental disposal problems. Control of oil shale char combustion is more easily managed if there is a knowledge of how the rate of combustion depends on O/sub 2/ concentration and temperature. This motivation led to an earlier study of the combustion kinetics of spent shale from the Parachute Creek Member in western Colorado. That study provided evidence that one or more of the mineral species present in the shale acted as an oxidation catalyst. Consequently it was decided to follow up on that investigation by examining the combustion activity of other oil shales; specifically those with differing elemental and/or mineral compositions. Six oil shale samples were selected for evaluation and comparison: one from the Parachute Creek Member (PCM), one from a deep core sample in the C-a tract (C-a), two from the saline zone in western Colorado (S-A and S-B), one from the Geokinetics site in eastern Utah (GEOK) and one sample of Antrim shale from Michigan (ANT). On the basis of the studies conducted here, it is readily apparent that the presence of minerals can drastically alter the reactivity of the residual char on spent oil shale. More detailed quantitative studies are necessary in order to be able to assess their importance under typical oil shale processing conditions and will be the subject of future manuscripts from this laboratory.

  4. Explosively produced fracture of oil shale

    NASA Astrophysics Data System (ADS)

    1981-10-01

    Explosive cratering experiments were conducted as a part of the research effort to study the explosively produced fracture of oil shale. They were designed to identify and analyze the major factors involved in the fracturing of oil shale, to provide data for the verification of the computer models, and ultimately to lead to the design of a rubble bed for in situ retorting oil shale. The rubble excavated from eight cratering experiments was separated and the volumes of rubble in each screened size category are presented. Also presented are the data from the detailed investigation of the joint/fracture attitudes (strikes and dips) within a crater interior after excavation. The data were tabulated and plotted to allow future comparisons and analyses pertinent to similar experiments. A brief discussion of the experiment site and the graphical representation of the data are included. Finally, since the homogeneity of the oil shale is an important consideration in the selection of a site for these explosive fracture experiments, cores were taken and analyzed. The identification of the geological parameters and their extent and how they delineate the overall characterization of the experiment site, including the subsurface geology, is given. It is shown how the postshot core analysis will indicate how the blast affected the rock.

  5. BX in-situ oil shale project. Annual status report on environmental monitoring and analysis-SP No. 6, March 1, 1980-February 28, 1981

    SciTech Connect

    1981-09-01

    The objective of the BX In Situ Oil Shale Project is to demonstrate the technical feasibility of using superheated steam as a heat-carrying medium to retort in situ the oil shale in the Green River Formation leached zone and provide a mechanism for the recovery of this shale oil with a minimum impact on the environment. Utilizing primarily the natural porosity in the leached zone, approximately one trillion Btus of heat will be injected into a site over a two-year period to heat to retorting temperature a shale zone approximately 550 feet thick and covering about one acre. The field project is located at Equity's BX In Situ site in Rio Blanco County in northwestern Colorado. Environmental activities conducted from March 1, 1980 through February 28, 1981 were a continuation of operational monitoring initiated the previous year that included meteorology, water quality and aquatic ecology monitoring.

  6. High efficiency shale oil recovery. Final report, January 1, 1992--June 30, 1993

    SciTech Connect

    Adams, D.C.

    1993-09-29

    The Adams Counter-current shale oil recovery process is an improved retorting technology enabling highly efficient oil recovery from oil shale. The high efficiency results primarily from the following facts: it (1) recovers the ash heat to preheat the feed ore; (2) burns and uses the coke energy and (3) operates without using hot ash recycling as a heat carrier. This latter feature is doubly important, contributing to high oil yield and to the generation of highly reactive coke which can be burned below 1000{degree}F, avoiding the endothermal calcination of the mineral carbonates and helping to clean the ash of contaminants. This project demonstrates that oil shale can be retorted under the specified conditions and achieve the objectives of very high efficiency. The project accomplished the following: 51 quartz sand rotary kiln runs provided significant engineering data. A heat transfer value of 107 Btu/hr/ft{sup 2}/{degree}F was obtained at optimum RPM; eight oil shale samples were obtained and preliminary shakedown runs were made. Five of the samples were selected for kiln processing and twelve pyrolysis runs were made on the five different oil shales;average off recovery was 109% of Fisher Assay; retorted residue from all five samples was oxidized at approximately 1000{degree}F. The ash from these runs was oxidized to varying extents, depending on the oil shale and oxidizing temperatures. While 1000{degree}F is adequately hot to provide process heat from coke combustion for these ores, some Eastern oil shales, without mineral carbonates, may be oxidized at higher temperatures, perhaps 100--300 degrees hotter, to obtain a more complete oxidation and utilization of the coke.

  7. Orientation of tectonic stresses in central Kentucky during U. Devonian/L. Mississippian times: Evidence from quartz veins (after gypsum) in NE-trending, systematic joints in shales

    SciTech Connect

    Grover, J.; Dupuis-Nouille, E.M. . Dept. of Geology)

    1992-01-01

    Quartz replacing fibrous gypsum and anhydrite pseudomorphically (QAS; quartz after sulfate''), and preserving characteristic crack-seal'' and chickenwire'' textures, occurs in extensional veins at four locations in central KY. The veins occupy a systematic set of NE-SW-trending, vertical joints within the essentially flat-lying shales of the Renfro Member of the Mississippian Borden Formation and the Late Devonian New Albany Shale. The four QAS occurrences discovered to date are located northeast of the Borden Front. At one site in the New Albany Shale, QAS veins show clear evidence of penecontemporaneous deformation. It is proposed that at all QAS locations, gypsum precipitated in incipient joints before complete lithification of the sediment, and grew perpendicular to the fractures to form extensional veins in the soft but firm muds. The orientations of the joints now marked by QAS veins are broadly consistent with regional patterns of NE-SW-trending systematic joints and lineaments in southern IN and in central and eastern KY. These systematic fracture patterns do not correspond directly to known basement faults or rift systems, although they are consistent with modern stress directions in eastern and western KY, measured in situ in wells and by earthquake fault-plane solutions. It is proposed that this systematic trend marks the regional tectonic stress pattern characteristic of southern IN and central and eastern KY at, and since the Late Devonian. The evidence of penecontemporaneous sedimentary deformation in joints of U. Devonian age, marked and preserved by quartz replacement of early gypsum, is sufficient to show that while the systematic NE-trending joint set in KY may also be modern it is not uniquely so.

  8. 1. Distant view shows Engine Room Building behind cranes. Retort ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    1. Distant view shows Engine Room Building behind cranes. Retort rings in foreground were once located in Engine Room Building. See photo WA-131-A-2. Building on left is Machine Shop. Boiler Building is in front of stack. - Pacific Creosoting Plant, Engine Room Building, 5350 Creosote Place, Northeast, Bremerton, Kitsap County, WA

  9. VIEW, LOOKING SOUTHEAST, OF TELLURIDE IRON WORKS RETORT USED FOR ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    VIEW, LOOKING SOUTHEAST, OF TELLURIDE IRON WORKS RETORT USED FOR FLASHING MERCURY OFF OF GOLD TO CREATE SOFT INGOTS CALLED "SPONGES." AT RIGHT ARE SAFES FOR STORING 22-POUND SPONGES WORTH OVER $60,000 EACH, CA. 1985. - Shenandoah-Dives Mill, 135 County Road 2, Silverton, San Juan County, CO

  10. 4. STRAIGHT ON VIEW OF CASTIRON RETORTS AT TOP OF ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    4. STRAIGHT ON VIEW OF CAST-IRON RETORTS AT TOP OF FURNACE SHOWING PORTION OF HOT BLAST STOVE AND TURNED HEAD. - Nassawango Iron Furnace, Furnace Road, 1.2 miles west of Maryland Route 12, Snow Hill, Worcester County, MD

  11. Chemical equilibria model analysis of Hope Creek eastern oil shale lysimeter leachate data

    SciTech Connect

    Essington, M.E.

    1989-09-01

    Leachates from field lysimeters containing an eastern oil shale, a retorted eastern oil shale, and an oil shale fines/retorted oil shale mixture were subjected to chemical equilibria analysis by the GEOCHEM model. Results of the chemical equilibria model analysis provided a more detailed characterization of the chemistry of oil shale materials. The aqueous chemistry of the lysimeter leachates is dominated by free ionic metal species and metal sulfate ion pairs. Activity diagrams shows that free metal ion activities (with the exception of Ca{sup 2+}) are directly related to SO{sub 4}{sup 2{minus}} activities. This suggests that the aqueous activities of the metals examined are not supported by metal sulfate solid phases. However, an examination of metal sulfate ion activity products (IAPs) as a function of time shows that the IAPs approach constant values after approximately 800 days of the field study. For the great majority of the metals examined, the IAP values suggest leachate undersaturation with respect to even the most stable metal sulfate phases. Leachates from all three materials are predicted by GEOCHEM to approach equilibrium with respect to gypsum and goethite. In addition, leachates from the oil shale lysimeter are predicted by GEOCHEM to approach equilibrium with respect to melanterite, Fe-jurbanite, franklinite, molybdite, and molybdic acid. Aluminum activities in all three lysimeter leachates fall within the stability region of several basic aluminum sulfates. However, Al{sup 3+} activities in the lysimeter leachates are not supported by sulfate phases. 34 refs., 15 figs., 2 tabs.

  12. The development of an integrated multistage fluid bed retorting process. Quarterly technical report, April 1, 1993--June 30, 1993

    SciTech Connect

    Carter, S.; Stehn, J.; Vego, A.

    1993-07-01

    This report summarizes the progress made on the development of an integrated multistage fluidized bed retorting process (KENTORT II) during the period of April 1, 1993 through June 30, 1993 under Cooperative Agreement No. DE-FC21-90MC27286 with the Morgantown Energy Technology Center, U.S. Department of Energy. The KENTORT II process includes integral fluidized bed zones for pyrolysis, gasification, and combustion of the oil shale. The purpose of this program is to design and test the KENTORT II process at the 50-lb/hr scale. The major activities for this quarter included: system leak proofing, cold flow testing, shake down of the data acquisition system, instrumentation verification, and preparation for hot operation. Once the tasks necessary for heat up are completed, shake down and operation of the Process Demonstration Unit will begin.

  13. Constructing a geomechanical model of the Woodford Shale, Cherokee Platform, Oklahoma, USA effects of confining stress and rock strength on fluid flow

    NASA Astrophysics Data System (ADS)

    Hair, Tyler J.

    A micro-indentation tool is used to estimate the strength of the Woodford Shale from whole core samples through the geometrical attributes (diameter and depth) of a 'dimple' produced by the tool on the rock's surface. The measured dimples are correlated graphically with the unconfined compressive strength and internal friction angle of the Woodford and integrated with contemporary stress data from earthquake focal mechanisms and mapped active faults. Right-lateral strike-slip motion on a deep, unnamed potential splay of the Wilzetta fault (Cherokee Platform, Lincoln County, Oklahoma) is representative of the contemporary stress state of the region. Vertical or near-vertical factures striking ˜ 030° from SHaz (˜ 077°) are the mechanical discontinuities most likely to be reactivated and allow fluids to flow along their surfaces. This reactivation will occur if the magnitude of pressure sources such as pore pressure or fluid pressure exceeds the reactivation pressure for that fracture surface.

  14. Proof-of-Concept Oil Shale Facility Environmental Analysis Program

    SciTech Connect

    Not Available

    1990-11-01

    The objectives of the Project are to demonstrate: (1) the Modified In- Situ (MIS) shale oil extraction process and (2) the application of CFBC technology using oil shale, coal and waste gas streams as fuels. The project will focus on evaluating and improving the efficiency and environmental performance of these technologies. The project will be modest by commercial standards. A 17-retort MIS system is planned in which two retorts will be processed simultaneously. Production of 1206-barrels per calendar day of raw shale oil and 46-megawatts of electricity is anticipated. West Virginia University coordinated an Environmental Analysis Program for the Project. Experts from around the country were retained by WVU to prepare individual sections of the report. These experts were exposed to all of OOSI's archives and toured Tract C-b and Logan Wash. Their findings were incorporated into this report. In summary, no environmental obstacles were revealed that would preclude proceeding with the Project. One of the most important objectives of the Project was to verify the environmental acceptability of the technologies being employed. Consequently, special attention will be given to monitoring environmental factors and providing state of the art mitigation measures. Extensive environmental and socioeconomic background information has been compiled for the Tract over the last 15 years and permits were obtained for the large scale operations contemplated in the late 1970's and early 1980's. Those permits have been reviewed and are being modified so that all required permits can be obtained in a timely manner.

  15. Proof-of-Concept Oil Shale Facility Environmental Analysis Program

    SciTech Connect

    Not Available

    1990-11-01

    The objectives of the Project are to demonstrate: (1) the Modified In- Situ (MIS) shale oil extraction process and (2) the application of CFBC technology using oil shale, coal and waste gas streams as fuels. The project will focus on evaluating and improving the efficiency and environmental performance of these technologies. The project will be modest by commercial standards. A 17-retort MIS system is planned in which two retorts will be processed simultaneously. Production of 1206-barrels per calendar day of raw shale oil and 46-megawatts of electricity is anticipated. West Virginia University coordinated an Environmental Analysis Program for the Project. Experts from around the country were retained by WVU to prepare individual sections of the report. These experts were exposed to all of OOSI`s archives and toured Tract C-b and Logan Wash. Their findings were incorporated into this report. In summary, no environmental obstacles were revealed that would preclude proceeding with the Project. One of the most important objectives of the Project was to verify the environmental acceptability of the technologies being employed. Consequently, special attention will be given to monitoring environmental factors and providing state of the art mitigation measures. Extensive environmental and socioeconomic background information has been compiled for the Tract over the last 15 years and permits were obtained for the large scale operations contemplated in the late 1970`s and early 1980`s. Those permits have been reviewed and are being modified so that all required permits can be obtained in a timely manner.

  16. DOE oil shale reference sample bank: Quarterly report, January-March 1987. [Samples from Kentucky and Colorado

    SciTech Connect

    Owen, L.B.

    1987-03-01

    The DOE Oil Shale Program was restructured in FY84 to implement a 5-year period of basic and applied research in the study of the phenomena involved in oil shale pyrolysis/retorting. The program calls for the study of two reference shales per year for a period of 5 years. Consequently, the program calls for the identification, acquisition, processing, characterization, storage, disbursement, and record keeping for ten reference shales in a period of 5 years. Terra Tek, Inc. received the DOE Reference Shale Sample Bank contract in October, 1985. Two FY86 reference shales have been acquired, processed and stored under inert gas. The Eastern shale, designated E86, was obtained from the Clegg Creek Member of the New Albany Shale at a quarry near Louisville, Kentucky in the first quarter of FY86. The Western shale was obtained from the Exxon Colony Mine, located near Parachute, Colorado, during the first quarter of FY86. Partial distributions of both shales have been made to DOE contractors. Complete descriptions of the reference shale locales, shale processing procedures and analytical characterization are provided in this report. 7 refs., 40 figs.

  17. Oil shale

    SciTech Connect

    Knutson, C.F.

    1981-10-01

    Significant oil shale development activities are taking place in the Piceance basin in northwestern Colorado and the Uinta basin in northeastern Utah. About 377,000 bbl/d of oil production capacity is in the planning or construction phase in the Piceance basin and about 240,000 bbl/d capacity in the Uinta basin. Completion of these projects will depend upon the political, environmental, and technical feasibility. Additional oil shale development of about 80,000 bbl/d is being planned for Brazil and Morocco. 3 figures.

  18. Anaerobic biological treatment of in-situ retort water

    SciTech Connect

    Ossio, E.; Fox, P.

    1980-03-01

    Anaerobic fermentation was successfully used in a laboratory-scale batch digester to remove soluble organics from retort water. Required pretreatment includes reduction of ammonia levels to 360 mg-N/l, pH adjustment to 7.0, sulfide control, and the addition of the nutrients, calcium, magnesium, and phoshorus. If the prescribed pretreatment is used, BOD/sub 5/ and COD removal efficiencies of 89 to 90% and 65 to 70% are achieved, respectively.

  19. Shales and swelling soils

    NASA Astrophysics Data System (ADS)

    Franklin, J. A.; Dimillio, A. F.; Strohm, W. E., Jr.; Vandre, B. C.; Anderson, L. R.

    The thirteen (13) papers in this report deal with the following areas: a shale rating system and tentative applications to shale performance; technical guidelines for the design and construction of shale embankments; stability of waste shale embankments; dynamic response of raw and stabilized Oklahoma shales; laboratory studies of the stabilization of nondurable shales; swelling shale and collapsing soil; development of a laboratory compaction degradation test for shales; soil section approach for evaluation of swelling potential soil moisture properties of subgrade soils; volume changes in compacted clays and shales on saturation; characterization of expansive soils; pavement roughness on expansive clays; and deep vertical fabric moisture barriers in swelling soils.

  20. Mechanical Characterization of Mancos Shale

    NASA Astrophysics Data System (ADS)

    Broome, S.; Ingraham, M. D.; Dewers, T. A.

    2015-12-01

    A series of tests on Mancos shale have been undertaken to determine the failure surface and to characterize anisotropy. This work supports additional studies which are being performed on the same block of shale; fracture toughness, permeability, and chemical analysis. Mechanical tests are being conducted after specimens were conditioned for at least two weeks at 70% constant relative humidity conditions. Specimens are tested under drained conditions, with the constant relative humidity condition maintained on the downstream side of the specimen. The upstream is sealed. Anisotropy is determined through testing specimens that have been cored parallel and perpendicular to the bedding plane. Preliminary results show that when loaded parallel to bedding the shale is roughly 50% weaker. Test are run under constant mean stress conditions when possible (excepting indirect tension, unconfined compression, and hydrostatic). Tests are run in hydrostatic compaction to the desired mean stress, then differential stress is applied axially in displacement control to failure. The constant mean stress condition is maintained by decreasing the confining pressure by half of the increase in the axial stress. Results will be compared to typical failure criteria to investigate the effectiveness of capturing the behavior of the shale with traditional failure theory. Sandia National Laboratories is a multi-program laboratory managed and operated by Sandia Corporation, a wholly owned subsidiary of Lockheed Martin Corporation, for the U.S. Department of Energy's National Nuclear Security Administration under contract DE-AC04-94AL85000. SAND2015-6107 A.

  1. A Transversely Isotropic Thermo-mechanical Framework for Oil Shale

    NASA Astrophysics Data System (ADS)

    Semnani, S. J.; White, J. A.; Borja, R. I.

    2014-12-01

    The present study provides a thermo-mechanical framework for modeling the temperature dependent behavior of oil shale. As a result of heating, oil shale undergoes phase transformations, during which organic matter is converted to petroleum products, e.g. light oil, heavy oil, bitumen, and coke. The change in the constituents and microstructure of shale at high temperatures dramatically alters its mechanical behavior e.g. plastic deformations and strength, as demonstrated by triaxial tests conducted at multiple temperatures [1,2]. Accordingly, the present model formulates the effects of changes in the chemical constituents due to thermal loading. It is well known that due to the layered structure of shale its mechanical properties in the direction parallel to the bedding planes is significantly different from its properties in the perpendicular direction. Although isotropic models simplify the modeling process, they fail to accurately describe the mechanical behavior of these rocks. Therefore, many researchers have studied the anisotropic behavior of rocks, including shale [3]. The current study presents a framework to incorporate the effects of transverse isotropy within a thermo-mechanical formulation. The proposed constitutive model can be readily applied to existing finite element codes to predict the behavior of oil shale in applications such as in-situ retorting process and stability assessment in petroleum reservoirs. [1] Masri, M. et al."Experimental Study of the Thermomechanical Behavior of the Petroleum Reservoir." SPE Eastern Regional/AAPG Eastern Section Joint Meeting. Society of Petroleum Engineers, 2008. [2] Xu, B. et al. "Thermal impact on shale deformation/failure behaviors---laboratory studies." 45th US Rock Mechanics/Geomechanics Symposium. American Rock Mechanics Association, 2011. [3] Crook, AJL et al. "Development of an orthotropic 3D elastoplastic material model for shale." SPE/ISRM Rock Mechanics Conference. Society of Petroleum Engineers

  2. UNOCAL 76: Parachute Creek Shale Oil Program. Environmental Monitoring Plan annual report, January 1-September 30, 1987

    SciTech Connect

    Not Available

    1988-03-31

    The Energy Security Act of 1980 established a program to provide financial assistance to private industry in the construction and operation of commercial-scale synthetic-fuels plants. The Parachute Creek Shale Oil Program is one of four projects awarded financial assistance. The Program agreed to comply with existing environmental-monitoring regulations and to develop an Environmental Monitoring Plan incorporating supplemental monitoring in the areas of water, air, solid waste, and worker health and safety during the period 1985-1992. The Program site includes three entities: the Mine/Retort, atop Long Ridge; the Upgrade Facility down valley; and the Retorted Shale Disposal area at the base of Long Ridge. Results of the first year of EMP monitoring are summarized in the document with emphasis on worker health surveillance.

  3. Sunlight activation of shale-oil byproducts as measured by genotoxic effects in cultured Chinese hamster cells

    SciTech Connect

    Strniste, G.F.; Chen, D.J.; Okinaka, R.T.

    1981-01-01

    Activation of certain classes of promutagens/procarcinogens can be accomplished by exposure to various radiation sources. Retort processes currently in use in the production of shale oil generate significant quantities of process waters which contain a wide spectrum of uv-absorbing, organic material. Photoactivation of these waters with an artificial source of NUV results in genotoxic events in cultured mammalian cells. Since significant amounts (2 to 4%) of solar radiation reaching the earth's surface is NUV, we were concerned about potential biological effects resulting from solar-irradiated waste streams. This paper summarizes new and previously published data concerning the induction of both cytotoxicity and mutagenicity in cultured Chinese hamster cells (line CHO) after their exposure to a particular oil shale retort process water and natural sunlight.

  4. Estimation of retorted phosphor powder from spent fluorescent lamps by thermal process.

    PubMed

    Park, Hun-Su; Rhee, Seung-Whee

    2016-04-01

    The degree of thermal stabilization of phosphor powder from spent fluorescent lamps (SFLs) manufactured by three companies (A, B, C) was estimated by examining mercury content in phosphor powder with retorting time, retorting temperature and rotational speed of drum. Mercury content of phosphor powders from spent fluorescent lamps manufactured by A, B and C companies as samples in thermal experiments was 4031 mg/kg, 3522 mg/kg and 3172 mg/kg, respectively. In the thermal experiments, the optimal conditions for retorting time, retorting temperature, and rotational speed were determined at 6h, 400°C, and 2.0 rpm, respectively. With thermal processing at the optimal conditions, mercury content of all samples for retorted phosphor powder was less than 3.0mg/kg, while efficiency of thermal process to control mercury content was higher than 99.9%. Leaching tests such as Toxicity Characteristic Leaching Procedure (TCLP) and Korea Extraction Test (KET) were subsequently carried out to verify if retorted phosphor powder is hazardous waste. Leaching concentrations of mercury for all samples of retorted phosphor powder were satisfied with regulatory levels in both leaching tests. Hence, retorted phosphor powders at the optimal conditions are considered to be non-hazardous wastes.

  5. Treatment of concentrated industrial wastewaters originating from oil shale and the like by electrolysis polyurethane foam interaction

    DOEpatents

    Tiernan, Joan E.

    1991-01-01

    Highly concentrated and toxic petroleum-based and synthetic fuels wastewaters such as oil shale retort water are treated in a unit treatment process by electrolysis in a reactor containing oleophilic, ionized, open-celled polyurethane foams and subjected to mixing and l BACKGROUND OF THE INVENTION The invention described herein arose in the course of, or under, Contract No. DE-AC03-76SF00098 between the U.S. Department of Energy and the University of California.

  6. Sedimentological, mineralogical and geochemical definition of oil-shale facies in the lower Parachute Creek Member of Green River Formation, Colorado

    SciTech Connect

    Cole, R.D.

    1984-04-01

    Sedimentological, mineralogical and geochemical studies of two drill cores penetrating the lower Saline zone of the Parachute Creek Member (middle L-4 oil-shale zone through upper R-2 zone) of the Green River Formation in north-central Piceance Creek basin, Colorado, indicate the presence of two distinct oil-shale facies. The most abundant facies has laminated stratification and frequently occurs in the L-4, L-3 and L-2 oil-shale zones. The second, and subordinate facies, has ''streaked and blebby'' stratification and is most abundant in the R-4, R-3 and R-2 zones. Laminated oil shale originated by slow, regular sedimentation during meromictic phases of ancient Lake Uinta, whereas streaked and blebby oil shale was deposited by episodic, non-channelized turbidity currents. Laminated oil shale has higher contents of nahcolite, dawsonite, quartz, K-feldspar and calcite, but less dolomite/ankerite and albite than streaked and blebby oil shale. Ca-Mg-Fe carbonate minerals in laminated oil shale have more variable compositions than those in streaked and blebby shales. Streaked and blebby oil shale has more kerogen and a greater diversity of kerogen particles than laminated oil shale. Such variations may produce different pyrolysis reactions when each shale type is retorted.

  7. Fault structure, stress, or pressure control of the seismicity in shale? Insights from a controlled experiment of fluid-induced fault reactivation

    NASA Astrophysics Data System (ADS)

    De Barros, Louis; Daniel, Guillaume; Guglielmi, Yves; Rivet, Diane; Caron, Hervé; Payre, Xavier; Bergery, Guillaume; Henry, Pierre; Castilla, Raymi; Dick, Pierre; Barbieri, Ernesto; Gourlay, Maxime

    2016-06-01

    Clay formations are present in reservoirs and earthquake faults, but questions remain on their mechanical behavior, as they can vary from ductile (aseismic) to brittle (seismic). An experiment, at a scale of 10 m, aims to reactivate a natural fault by fluid pressure in shale materials. The injection area was surrounded by a dense monitoring network comprising pressure, deformation, and seismicity sensors, in a well-characterized geological setting. Thirty-two microseismic events were recorded during several injection phases in five different locations within the fault zone. Their computed magnitude ranged between -4.3 and -3.7. Their spatiotemporal distribution, compared with the measured displacement at the injection points, shows that most of the deformation induced by the injection is aseismic. Whether the seismicity is controlled by the fault architecture, mineralogy of fracture filling, fluid, and/or stress state is then discussed. The fault damage zone architecture and mineralogy are of crucial importance, as seismic slip mainly localizes on the sealed-with-calcite fractures which predominate in the fault damage zone. As no seismicity is observed in the close vicinity of the injection areas, the presence of fluid seems to prevent seismic slips. The fault core acts as an impermeable hydraulic barrier that favors fluid confinement and pressurization. Therefore, the seismic behavior seems to be strongly sensitive to the structural heterogeneity (including permeability) of the fault zone, which leads to a heterogeneous stress response to the pressurized volume.

  8. Study of reverse osmosis for treating oil-shale in-situ wastewaters. Final report

    SciTech Connect

    Hicks, R.E.; Liang, L.

    1981-01-31

    The results of a study to determine the feasibility of using reverse osmosis for the treatment of the three major wastewater streams evolved during modified in-situ oil shale processing: gas condensate, retort water and excess mine drainage water, are presented in this report. Data was obtained from laboratory tests on real wastewaters treated with composite reverse osmosis membranes. It was found that reverse osmosis can be used to treat retort waters to a quality suitable for reuse within the plant while it can be used to treat excess mine drainage waters for discharge to a receiving stream. Furthermore, although reverse osmosis is also a feasible process for the treatment of gas condensate, a better treatment appears to be steam stripping which alone can produce a water of a quality suitable for plant reuse. The annual operating costs of treating mine drainage waters range from $2.00 to $2.30 per 1000 gallons of permeate while the costs of treating retort waters range from $2.70 to $2.90 per 1000 gallons of permeate, exclusive of the costs of concentrate disposal. The major uncertainty in the use of reverse osmosis for treating oil shale wastewaters is membrane lifetime. Recommendations are made for a field test program to determine the long term susceptibility of composite membranes to fouling and/or degradation.

  9. High efficiency shale oil recovery. Second quarterly report, April 1, 1992--June 30, 1992

    SciTech Connect

    Adams, C.D.

    1992-07-18

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated at bench-scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although an oil shale batch sample is sealed in the batch kiln from the start until the end of the run, the process conditions for the batch are the same as the conditions that an element of oil shale would encounter in a larger continuous process kiln. For example, similar conditions of heatup rate, oxidation of the residue and cool-down prevail for the element in both systems. This batch kiln is a unit constructed in a 1987 Phase I SBIR tar sand retorting project. The kiln worked fairly well in that project; however, the need for certain modifications was observed. These modifications are now underway to simplify the operation and make the data and analysis more exact. The second quarter agenda consisted of (a) kiln modifications; (b) sample preparation; and (c) Heat Transfer calibration runs (part of proposal task number 3 -- to be completed by the end of month 7).

  10. High efficiency shale oil recovery. Fifth quarterly report, January 1, 1993--March 31, 1993

    SciTech Connect

    Adams, D.C.

    1993-04-22

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated on a small scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although an oil shale batch sample is sealed in the batch kiln from the start until the end of the run, the process conditions for the batch are the same as the conditions that an element of oil shale would encounter in a continuous process kiln. Similar chemical and physical conditions (heating, mixing, pyrolysis, oxidation) exist in both systems.The two most important data objectives in this phase of the project are to demonstrate (1) that the heat recovery projected for this project is reasonable and (2) that an oil shale kiln will run well and not plug up due to sticking and agglomeration. The following was completed this quarter. (1) Twelve pyrolysis runs were made on five different oil shales. All of the runs exhibited a complete absence of any plugging, tendency. Heat transfer for Green River oil shale in the rotary kiln was 84.6 Btu/hr/ft{sup 2}/{degrees}F, and this will provide for ample heat exchange in the Adams kiln. (2) One retorted residue sample was oxidized at 1000{degrees}F. Preliminary indications are that the ash of this run appears to have been completely oxidized. (3) Further minor equipment repairs and improvements were required during the course of the several runs.

  11. Experimental drilling in Chattanooga shale

    USGS Publications Warehouse

    Brown, Andrew

    1948-01-01

    Information on which specifications were originally drawn for drilling the Chattanooga shale was obtained largely from the TVA, whose geologists and driller laid great stress on the difficulties of maintaining circulation in their ho;es. The stated that the shale itself was not particularly difficult to core, the trouble being in the overburden. They did not use deep casing, depending on cementing to hold the holes open. On this basis, the Survey's specifications called for mid casing only, it being assumed that solid rock would be encountered at relatively shallow depths. This belief was borne out by examination of such road cuts and other exposures as were available.

  12. Geochemistry of Brazilian oil shales

    SciTech Connect

    Neto, C.C.

    1983-02-01

    A general survey of the main brazilian oil shale formations presenting their location, oil reserve, age and stratigraphy introduces this paper. It is followed by a comparative survey of the data on chemical composition (elementary, minerals and organic constituents/biological markers) and of thermal alteration indexes in order to define their maturity. The geochemical phenomena involved with a large diabase intrusion in the Irati formation is particularly stressed. The analytical methods of Solid Phase Extraction and Functional Group Marker developed for the analysis of bitumens and kerogens and the results obtained from the application of these methods to brazilian oil shales are discussed. The paper ends with a brief description of a comprehensive analytical bibliography on brazilian oil shales prepared to serve as a data base for these organites.

  13. Converting oil shale to liquid fuels: energy inputs and greenhouse gas emissions of the Shell in situ conversion process.

    PubMed

    Brandt, Adam R

    2008-10-01

    Oil shale is a sedimentary rock that contains kerogen, a fossil organic material. Kerogen can be heated to produce oil and gas (retorted). This has traditionally been a CO2-intensive process. In this paper, the Shell in situ conversion process (ICP), which is a novel method of retorting oil shale in place, is analyzed. The ICP utilizes electricity to heat the underground shale over a period of 2 years. Hydrocarbons are produced using conventional oil production techniques, leaving shale oil coke within the formation. The energy inputs and outputs from the ICP, as applied to oil shales of the Green River formation, are modeled. Using these energy inputs, the greenhouse gas (GHG) emissions from the ICP are calculated and are compared to emissions from conventional petroleum. Energy outputs (as refined liquid fuel) are 1.2-1.6 times greater than the total primary energy inputs to the process. In the absence of capturing CO2 generated from electricity produced to fuel the process, well-to-pump GHG emissions are in the range of 30.6-37.1 grams of carbon equivalent per megajoule of liquid fuel produced. These full-fuel-cycle emissions are 21%-47% larger than those from conventionally produced petroleum-based fuels.

  14. A STUDY OF THE CONCENTRATIONS OF POLYCYCLIC AROMATIC HYDROCARBONS IN GAS WORKS RETORT HOUSES

    PubMed Central

    Lawther, P. J.; Commins, B. T.; Waller, R. E.

    1965-01-01

    Measurements of the concentration of 3:4-benzpyrene and other polycyclic aromatic hydrocarbons have been made in gas works retort houses of several types. The tarry fumes which escaped from retorts contained extremely high concentrations of polycyclic hydrocarbons, but in general men were only exposed to these very briefly. The mean concentration of 3:4-benzpyrene determined from long-period samples at sites representative of normal working conditions in three works was 3 μg./m.3, over 100 times the normal level in the City of London. Above the retorts in an old horizontal retort house the concentration was over 200 μg./m.3, about 10,000 times that in the City, and the `top-man' working there could be exposed to this in the normal course of his duty. We found no working areas in the vertical retort houses where men could be exposed to such massive concentrations of polycyclic hydrocarbons. Apart from defining these special conditions above horizontal retorts our results did not reveal any gross differences in pollution of the general air in horizontal and continuous vertical retort houses. Images PMID:14261701

  15. Molecular characterization and comparison of shale oils generated by different pyrolysis methods using FT-ICR mass spectrometry

    USGS Publications Warehouse

    Jin, J.M.; Kim, S.; Birdwell, J.E.

    2011-01-01

    Fourier transform ion cyclotron resonance mass spectrometry (FT ICR-MS) was applied in the analysis of shale oils generated using two different pyrolysis systems under laboratory conditions meant to simulate surface and in situ oil shale retorting. Significant variations were observed in the shale oils, particularly the degree of conjugation of the constituent molecules. Comparison of FT ICR-MS results to standard oil characterization methods (API gravity, SARA fractionation, gas chromatography-flame ionization detection) indicated correspondence between the average Double Bond Equivalence (DBE) and asphaltene content. The results show that, based on the average DBE values and DBE distributions of the shale oils examined, highly conjugated species are enriched in samples produced under low pressure, high temperature conditions and in the presence of water.

  16. Heat and mass transfer processes during the pyrolysis of antrim oil shale

    NASA Astrophysics Data System (ADS)

    Piccirelli, R. A.

    1980-07-01

    A model of simultaneous heat and mass transfer processes during the pyrolysis of slabs of consolidated Michigan oil shale is presented. The manner in which the transport processes control the yield of pyrolysis product is emphasized; the model parameters are selected to reflect the conditions expected during in situ retorting. A single reaction describes the generation of gaseous pyrolysis product; numerical solution of the model mass transport equations indicates that the pressure and velocity profiles within the shale due to generation of gaseous reaction products can be assumed to be in a quasi-steady state. It is concluded that while the bulk convective transport is not essential to the energy equation, it is important for product yield calculations; the solution also suggests that the heat transfer through the surface convective layer and into the shale slab is the rate limiting process.

  17. Calorimetric determination of the heat of combustion of spent Green River shale at 978 K

    SciTech Connect

    Mraw, S.C.; Keweshan, C.F.

    1987-08-01

    A Calvet-type calorimeter was used to measure heats of combustion of spent Colorado oil shales. For Green River shale, the samples were members of a sink-float series spanning oil yields from 87 to 340 L . tonne/sup -1/. Shale samples (30-200 mg) are dropped into the calorimeter at high temperature, and a peak in the thermopile signal records the total enthalpy change of the sample between room temperature and the final temperature. Duplicate samples from the above sink-float series were first retorted at 773 K and then dropped separately into nitrogen and oxygen at 978 K. The resulting heats are subtracted to give the heat of combustion, and the results are compared to values from classical bomb calorimetry. The agreement shows that the heats of combustion of the organic component are well understood but that question remain on the reactions of the mineral components.

  18. Explosive fragmentation of oil shale: Results from Colony and Anvil Points Mines, Colorado

    SciTech Connect

    Dick, R.D.; Fourney, W.L.; Young, C. III

    1992-12-31

    From 1978 through 1983, numerous oil shale fragmentation tests were conducted at the Colony and Anvil Points Mines, Colorado. These experiments were part of an investigation to determine factors required for the adequate fragmentation of oil shale and to evaluate the feasibility of using the vertical modified in situ retort (VMIS) method for recovery of kerogen from oil shale. The objective of this research was to support the design of a large volume (10{sup 4} m{sup 3}) rubble bed for in situ processing. In addition, this rubble bed was to be formed in a large single-blast event which included decked charges, time delays, and multiple boreholes. Results are described.

  19. Characterization of porous media properties and leaching capacity of spent oil shales

    SciTech Connect

    Ramirez, W.F.; Morelli, P.T.

    1981-01-01

    Porous media properties of spent oil shales have been determined in order to provide fundamental data needed to identify and predict the transport of leachates through surface piles or abandoned modified insitu retorts. Using high pressure mercury porosimetry, pore size distributions were measured. Specific surface areas were measured using both the mercury intrusion technique as well as BET (Brunauer-Emmett-Teller) nitrogen adsorption. Visual and chemical analyses were performed by scanning electron microscopy and x-ray fluorescence spectroscopy. Leaching capacities of the various spent shale samples were measured using equilibrium leaching studies to determine Equilibrium Exchange Isotherms. Based on these characterization studies, fundamental modeling concepts have benn established for the transport of leachates through spent oil shales. 13 refs.

  20. Reclamation studies on oil shale lands in northwestern Colorado

    SciTech Connect

    Cook, C.W.; Redente, E.F.

    1980-02-01

    The overall objective of this project is to study the effects of various reclamation practices on above- and belowground ecosystem development associated with disturbed oil shale lands in northwestern Colorado. Plant growth media that are being used in field test plots include retorted shale, soil over retorted shale, subsoil materials, and surface disturbed topsoils. Some of the more significant results are: (1) a soil cover of at least 61 cm in conjunction with a capiallary barrier provided the best combination of treatments for the establishment of vegetation and a functional microbial community, (2) aboveground production values for native and introduced species mixtures are comparable after three growing seasons, (3) cover values for native species mixtures are generally greater than for introduced species, (4) native seed mixtures, in general, allow greater invasion to occur, (5) sewage sludge at relatively low rates appears to provide the most beneficial overall effect on plant growth, (6) cultural practices, such as irrigated and mulching have significant effects on both above- and belowground ecosystem development, (7) topsoil storage after 1.5 years does not appear to significantly affect general microbial activities but does reduce the mycorrhizal infection potential of the soil at shallow depths, (8) populations of mycorrhizal fungi are decreased on severely disturbed soils if a cover of vegetation is not established, (9) significant biological differences among ecotypes of important shrub species have been identified, (10) a vegetation model is outlined which upon completion will enable the reclamation specialist to predict the plant species combinations best adapted to specific reclamation sites, and (11) synthetic strains of two important grass species are close to development which will provide superior plant materials for reclamation in the West.

  1. High efficiency shale oil recovery. Fourth quarterly report, October 1, 1992--December 31, 1992

    SciTech Connect

    Adams, D.C.

    1992-12-31

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated on a small scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although an oil shale batch sample is sealed in the batch kiln from the start until the end of the run, the process conditions for the batch are the same as the conditions that an element of oil shale would encounter in a continuous process kiln. Similar chemical and physical (heating, mixing) conditions exist in both systems. The two most important data objectives in this phase of the project are to demonstrate (1) that the heat recovery projected for this project is reasonable and (2) that an oil shale kiln will run well and not plug up due to sticking and agglomeration. The following was completed and is reported on this quarter: (1) A software routine was written to eliminate intermittently inaccurate temperature readings. (2) We completed the quartz sand calibration runs, resolving calibration questions from the 3rd quarter. (3) We also made low temperature retorting runs to identify the need for certain kiln modifications and kiln modifications were completed. (4) Heat Conductance data on two Pyrolysis runs were completed on two samples of Occidental oil shale.

  2. Helium release during shale deformation: Experimental validation

    NASA Astrophysics Data System (ADS)

    Bauer, Stephen J.; Gardner, W. Payton; Heath, Jason E.

    2016-07-01

    This work describes initial experimental results of helium tracer release monitoring during deformation of shale. Naturally occurring radiogenic 4He is present in high concentration in most shales. During rock deformation, accumulated helium could be released as fractures are created and new transport pathways are created. We present the results of an experimental study in which confined reservoir shale samples, cored parallel and perpendicular to bedding, which were initially saturated with helium to simulate reservoir conditions, are subjected to triaxial compressive deformation. During the deformation experiment, differential stress, axial, and radial strains are systematically tracked. Release of helium is dynamically measured using a helium mass spectrometer leak detector. Helium released during deformation is observable at the laboratory scale and the release is tightly coupled to the shale deformation. These first measurements of dynamic helium release from rocks undergoing deformation show that helium provides information on the evolution of microstructure as a function of changes in stress and strain.

  3. Multicomponent seismic monitoring of stress arching in the overburden due to hydraulic fracturing in the Montney Shale at Pouce Coupe Field, Alberta, Canada

    NASA Astrophysics Data System (ADS)

    Vinal, Irene

    Recent studies have shown convincing evidence that time-lapse changes in seismic data occur not only within the reservoir interval but also in the overburden. Observations that production at the reservoir level and subsequent decrease in pore pressure lead to modifications in the stress field and variations in the overburden have been documented (Hatchell et al., 2003; Hudson et al., 2005). The study of the opposite case, that is, the analysis of the effect in the overburden of an increase in pore pressure in the reservoir has not been so well documented yet and is the focus of this work; the possibility that the hydraulic fracturing process causes seismically detectable changes in the overburden in a time-lapse sense is studied at Pouce Coupe Field, Alberta, and the results are shown. The analysis is performed using multicomponent data from three seismic surveys acquired to evaluate the hydraulic stimulations of two horizontal wells in the Montney Shale. The time-lapse time shifts between the data of the two monitor surveys and the baseline have been calculated and constitute the main tool to study the injection-induced changes above the reservoir interval. The hypothesis is that the increase in the reservoir pressure due to the hydraulic well treatment might produce upward overburden compaction, leading to an increase in stresses that would be translated into an increase in the seismic velocities and therefore, into positive time shifts (considering monitor data subtracted from baseline data) if a time window for the overburden is analyzed. The study shows strong differences in the magnitude of the PS response to the stimulations compared to that of the PP data. The fact that mode-converted (PS) waves are more sensitive to azimuthal anisotropy than compressional waves explains the stronger character of the response observed in PS data, allowing for a more detailed interpretation of the stress-arching distribution. The time-lapse time shifts in the overburden

  4. The Devonian Marcellus Shale and Millboro Shale

    USGS Publications Warehouse

    Soeder, Daniel J.; Enomoto, Catherine B.; Chermak, John A.

    2014-01-01

    The recent development of unconventional oil and natural gas resources in the United States builds upon many decades of research, which included resource assessment and the development of well completion and extraction technology. The Eastern Gas Shales Project, funded by the U.S. Department of Energy in the 1980s, investigated the gas potential of organic-rich, Devonian black shales in the Appalachian, Michigan, and Illinois basins. One of these eastern shales is the Middle Devonian Marcellus Shale, which has been extensively developed for natural gas and natural gas liquids since 2007. The Marcellus is one of the basal units in a thick Devonian shale sedimentary sequence in the Appalachian basin. The Marcellus rests on the Onondaga Limestone throughout most of the basin, or on the time-equivalent Needmore Shale in the southeastern parts of the basin. Another basal unit, the Huntersville Chert, underlies the Marcellus in the southern part of the basin. The Devonian section is compressed to the south, and the Marcellus Shale, along with several overlying units, grades into the age-equivalent Millboro Shale in Virginia. The Marcellus-Millboro interval is far from a uniform slab of black rock. This field trip will examine a number of natural and engineered exposures in the vicinity of the West Virginia–Virginia state line, where participants will have the opportunity to view a variety of sedimentary facies within the shale itself, sedimentary structures, tectonic structures, fossils, overlying and underlying formations, volcaniclastic ash beds, and to view a basaltic intrusion.

  5. Sorption-desorption capacity of oil shale materials. Volume 2. Experimental methods and results. [2-hydroxynaphthalene, 1,2,3,4-tetrahydroquinoline, and 2,3,5-trimethylphenol

    SciTech Connect

    Boardman, G.D.; Godrej, A.N.; Cowher, D.M.; Lu, Y.W.

    1985-12-01

    The primary objective of this research was to evaluate the sorption/desorption (S/D) behavior of several inorganic and organic agents in the presence of four shales (Antrim, Anvil Points, Oxy 6, and Run 16) and a western soil. In addition, an attempt was made to relate batch test results to data obtained in continuous-flow, column trials, and to develop a spectrophotometric method for the analysis of organic compound mixtures. With respect to the results of studies with the inorganic agents, it appeared that retort temperature and porosity (and/or hydraulic conductivity) was strongly correlated to the distribution and quantity of inorganic agents which eluted from the shales. Most of the inorganic agents eluted from columns of the shales in the first two to eight pore volumes of effluent. Shales retorted at a lower temperature appeared to have a greater capacity for arsenic, cadmium, and fluoride removals than the other shales considered. Arsenic, cadmium, and iron were generally removed to below detection limits. In the case of cadmium and iron, removals were effected largely by precipitation due to the relatively high pH of the shale surfaces and associated fluids. Experiments with the organic agents indicated that 2-hydroxy-naphthalene was generally sorbed better than 1,2,3,4-tetrahydroquinoline which in most trials was more completely sorbed than 2,3,5-trimethylphenol. Overall, it appeared that Antrim shale was the best sorbent for the organic agents considered and Run 16 was generally the worst. Anvil Points and Oxy 6 shales often ranked intermediate to the other shales as sorbents and provided similar results. The western soil provided for sorption levels of the organics which were nearly as good, if not better, than those accomplished by the shales. 188 refs., 100 figs., 21 tabs.

  6. Assessment and control of water contamination associated with shale oil extraction and processing. Progress report, October 1, 1979-September 30, 1980

    SciTech Connect

    Peterson, E.J.; Henicksman, A.V.; Fox, J.P.; O'Rourke, J.A.; Wagner, P.

    1982-04-01

    The Los Alamos National Laboratory's research on assessment and control of water contamination associated with oil shale operations is directed toward the identification of potential water contamination problems and the evaluation of alternative control strategies for controlling contaminants released into the surface and underground water systems from oil-shale-related sources. Laboratory assessment activities have focused on the mineralogy, trace element concentrations in solids, and leaching characteristics of raw and spent shales from field operations and laboratory-generated spent shales. This report details the chemical, mineralogic, and solution behavior of major, minor, and trace elements in a variety of shale materials (spent shales from Occidental retort 3E at Logan Wash, raw shale from the Colony mine, and laboratory heat-treated shales generated from Colony mine raw shale). Control technology research activities have focused on the definition of control technology requirements based on assessment activities and the laboratory evaluation of alternative control strategies for mitigation of identified problems. Based on results obtained with Logan Wash materials, it appears that the overall impact of in situ processing on groundwater quality (leaching and aquifer bridging) may be less significant than previously believed. Most elements leached from MIS spent shales are already elevated in most groundwaters. Analysis indicates that solubility controls by major cations and anions will aid in mitigating water quality impacts. The exceptions include the trace elements vanadium, lead, and selenium. With respect to in situ retort leaching, process control and multistaged counterflow leaching are evaluated as alternative control strategies for mitigation of quality impacts. The results of these analyses are presented in this report.

  7. 77 FR 25206 - Proposed Extension of Existing Information Collection; Underground Retorts

    Federal Register 2010, 2011, 2012, 2013, 2014

    2012-04-27

    ... Safety and Health Administration Proposed Extension of Existing Information Collection; Underground Retorts AGENCY: Mine Safety and Health Administration, Labor. ACTION: Request for public comments. SUMMARY: The Department of Labor, as part of its continuing effort to reduce paperwork and respondent...

  8. Modeling of hydrologic conditions and solute movement in processed oil shale waste embankments under simulated climatic conditions

    SciTech Connect

    Reeves, T.L.; Turner, J.P.; Hasfurther, V.R.; Skinner, Q.D.

    1992-06-01

    The scope of this program is to study interacting hydrologic, geotechnical, and chemical factors affecting the behavior and disposal of combusted processed oil shale. The research combines bench-scale testing with large scale research sufficient to describe commercial scale embankment behavior. The large scale approach was accomplished by establishing five lysimeters, each 7.3 [times] 3.0 [times] 3.0 m deep, filled with processed oil shale that has been retorted and combusted by the Lurgi-Ruhrgas (Lurgi) process. Approximately 400 tons of Lurgi processed oil shale waste was provided by RBOSC to carry out this study. Research objectives were designed to evaluate hydrologic, geotechnical, and chemical properties and conditions which would affect the design and performance of large-scale embankments. The objectives of this research are: assess the unsaturated movement and redistribution of water and the development of potential saturated zones and drainage in disposed processed oil shale under natural and simulated climatic conditions; assess the unsaturated movement of solubles and major chemical constituents in disposed processed oil shale under natural and simulated climatic conditions; assess the physical and constitutive properties of the processed oil shale and determine potential changes in these properties caused by disposal and weathering by natural and simulated climatic conditions; assess the use of previously developed computer model(s) to describe the infiltration, unsaturated movement, redistribution, and drainage of water in disposed processed oil shale; evaluate the stability of field scale processed oil shale solid waste embankments using computer models.

  9. Modeling of hydrologic conditions and solute movement in processed oil shale waste embankments under simulated climatic conditions

    SciTech Connect

    Reeves, T.L.; Turner, J.P.; Hasfurther, V.R.; Skinner, Q.D.

    1992-06-01

    The scope of this program is to study interacting hydrologic, geotechnical, and chemical factors affecting the behavior and disposal of combusted processed oil shale. The research combines bench-scale testing with large scale research sufficient to describe commercial scale embankment behavior. The large scale approach was accomplished by establishing five lysimeters, each 7.3 {times} 3.0 {times} 3.0 m deep, filled with processed oil shale that has been retorted and combusted by the Lurgi-Ruhrgas (Lurgi) process. Approximately 400 tons of Lurgi processed oil shale waste was provided by RBOSC to carry out this study. Research objectives were designed to evaluate hydrologic, geotechnical, and chemical properties and conditions which would affect the design and performance of large-scale embankments. The objectives of this research are: assess the unsaturated movement and redistribution of water and the development of potential saturated zones and drainage in disposed processed oil shale under natural and simulated climatic conditions; assess the unsaturated movement of solubles and major chemical constituents in disposed processed oil shale under natural and simulated climatic conditions; assess the physical and constitutive properties of the processed oil shale and determine potential changes in these properties caused by disposal and weathering by natural and simulated climatic conditions; assess the use of previously developed computer model(s) to describe the infiltration, unsaturated movement, redistribution, and drainage of water in disposed processed oil shale; evaluate the stability of field scale processed oil shale solid waste embankments using computer models.

  10. Characteristics and potential of Antrim shale for in-situ energy production

    SciTech Connect

    Abubakr, S.M.

    1982-01-01

    A mathematical model was studied based on heat conduction into the formation from a hot well fueled by effluent gas and air. The model showed that the net energy production does not justify the process economically. Improvements on this model by higher temperature driving force for conduction, and by making a larger surface area accessible to combustion zone were investigated. Another mechanism considered was diffusion or forcing of air into the rock, followed by combustion of residual carbon deposited within the spent shale. Laboratory experiments simulating in situ energy production under a variety of conditions were performed to investigate these possibilities. Experiments showed that when shale is heated to about 1800/sup 0/F glazing occurs, blocking gas flow in or out of the rock. The compressibility of retorted shale, containing porosity of 20%, was only 1.6%. Thus the porosity formed is of little use in producing space or fractures. The opening of horizontal cracks during retorting under atmospheric pressure provided an important mechanism for the release of organic matter and the penetration of air into them. This was evident by the disappearance of carbonaceous residue along the cracks' surface. However, experiments performed under simulated overburden pressure showed no cracks and, therefore, this mechanism would be eliminated for true in situ energy production from Antrim.

  11. The Study of Heat Penetration of Kimchi Soup on Stationary and Rotary Retorts

    PubMed Central

    Cho, Won-Il; Park, Eun-Ji; Cheon, Hee Soon; Chung, Myong-Soo

    2015-01-01

    The aim of this study was to determine the heat-penetration characteristics using stationary and rotary retorts to manufacture Kimchi soup. Both heat-penetration tests and computer simulation based on mathematical modeling were performed. The sterility was measured at five different positions in the pouch. The results revealed only a small deviation of F0 among the different positions, and the rate of heat transfer was increased by rotation of the retort. The thermal processing of retort-pouched Kimchi soup was analyzed mathematically using a finite-element model, and optimum models for predicting the time course of the temperature and F0 were developed. The mathematical models could accurately predict the actual heat penetration of retort-pouched Kimchi soup. The average deviation of the temperature between the experimental and mathematical predicted model was 2.46% (R2=0.975). The changes in nodal temperature and F0 caused by microbial inactivation in the finite-element model predicted using the NISA program were very similar to that of the experimental data of for the retorted Kimchi soup during sterilization with rotary retorts. The correlation coefficient between the simulation using the NISA program and the experimental data was very high, at 99%. PMID:25866751

  12. Fracture toughness of Antrim shale

    SciTech Connect

    Kim, K.; Mubeen, A.

    1980-05-01

    Fracture toughness of Antrim shale cores from Dow Chemical's Sanilac County test site in Michigan were measured by the burst test method developed by Clifton et al. (1976). These tests were conducted to establish a preliminary data base to be used for the designing of a bed preparation method and prediction of rock fracture behavior under various loading conditions such as explosives and hydraulic fracturing for in-situ processing of oil shale. The test method was chosen because the thick-walled cylinder provides a loading and specimen configuration similar to in-situ hydraulic fracturing operations and the specimens can be conveniently prepared from diamond drill cores for laboratory tests. Further, the nature of variation of crack tip stress intensity in this specimen is such that K/sub IC/ does not depend on initial crack length, and crack propagation need not be monitored. The test results show that the fracture toughness of typical Antrim shale core range from 930 to 1080 psi ..sqrt..in. while the limestone specimens, a basement rock, range from 1240 to 1430 psi ..sqrt..in. These values are close to that of lean Western oil shale from Anvil point, Colorado (Schmidt, 1977), i.e., 980 psi ..sqrt..in.

  13. Geomechanical Characterization of Marcellus Shale

    NASA Astrophysics Data System (ADS)

    Villamor Lora, Rafael; Ghazanfari, Ehsan; Asanza Izquierdo, Enrique

    2016-09-01

    Understanding the reservoir conditions and material properties that govern the geomechanical behavior of shale formations under in situ conditions is of vital importance for many geomechanical applications. The development of new numerical codes and advanced multi-physical (thermo-hydro-chemo-mechanical) constitutive models has led to an increasing demand for fundamental material property data. Previous studies have shown that deformational rock properties are not single-value, well-defined, linear parameters. This paper reports on an experimental program that explores geomechanical properties of Marcellus Shale through a series of isotropic compression (i.e. σ 1 = σ 2 = σ 3) and triaxial (i.e. σ 1 > σ 2 = σ 3) experiments. Deformational and failure response of these rocks, as well as anisotropy evolution, were studied under different stress and temperature conditions using single- and multi-stage triaxial tests. Laboratory results revealed significant nonlinear and pressure-dependent mechanical response as a consequence of the rock fabric and the occurrence of microcracks in these shales. Moreover, multi-stage triaxial tests proved to be useful tools for obtaining failure envelopes using a single specimen. Furthermore, the anisotropic nature of Marcellus Shale was successfully characterized using a three-parameter coupled model.

  14. High efficiency shale oil recovery. First quarter report, January 1, 1992--March 31, 1992

    SciTech Connect

    Adams, D.C.

    1992-12-01

    The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated at bench-scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although a batch oil shale sample will be sealed in the batch kiln from the start until the end of the run, the process conditions for the batch will be the same as the conditions that an element of oil shale would encounter in a large continuous process kiln. For example, similar conditions of heat-up rate (20 deg F/min during the pyrolysis), oxidation of the residue and cool-down will prevail for the element in both systems. This batch kiln is a unit constructed in a 1987 Phase I SBIR tar sand retorting project. The kiln worked fairly well in that project; however, the need for certain modifications was observed. These modifications are now underway to simplify the operation and make the data and analysis more exact. The agenda for the first three months of the project consisted of the first of nine tasks and was specified as the following four items: 1. Sample acquisition and equipment alteration: Obtain seven oil shale samples, of varying grade each 10 lb or more, and samples of quartz sand. Order equipment for kiln modification. 3. Set up and modify kiln for operation, including electric heaters on the ends of the kiln. 4. Connect data logger and make other repairs and changes in rotary batch kiln.

  15. Western oil shale development: a technology assessment. Volume 8. Health effects of oil shale development

    SciTech Connect

    Rotariu, G.J.

    1982-02-01

    Information on the potential health effects of a developing oil shale industry can be derived from two major sources: (1) the historical experience in foreign countries that have had major industries; and (2) the health effects research that has been conducted in the US in recent years. The information presented here is divided into two major sections: one dealing with the experience in foreign countries and the second dealing with the more recent work associated with current oil shale development in the US. As a result of the study, several observations can be made: (1) most of the current and historical data from foreign countries relate to occupational hazards rather than to impacts on regional populations; (2) neither the historical evidence from other countries nor the results of current research have shown pulmonary neoplasia to be a major concern, however, certain types of exposure, particularly such mixed source exposures as dust/diesel or dust/organic-vapor have not been adequately studied and the lung cancer question is not closed; (3) the industry should be alert to the incidence of skin disease in the industrial setting, however, automated techniques, modern industrial hygiene practices and realistic personal hygiene should greatly reduce the hazards associated with skin contact; and (4) the entire question of regional water contamination and any resultant health hazard has not been adequately addressed. The industrial practice of hydrotreating the crude shale oil will diminish the carcinogenic hazard of the product, however, the quantitative reduction of biological activity is dependent on the degree of hydrotreatment. Both Soviet and American experimentalists have demonstrated a correlation betweed carcinogenicity/toxicity and retorting temperature; the higher temperatures producing the more carcinogenic or toxic products.

  16. Unocal Parachute Creek Shale Oil Program environmental monitoring program. Annual report, October 1, 1989-September 30, 1990

    SciTech Connect

    Not Available

    1991-03-31

    The Energy Security Act of 1980 established a program to provide financial assistance to private industry in the construction and operation of commercial-scale synthetic fuels plants. The Parachute Creek Shale Oil Program is one of four projects awarded financial assistance. The support agreement included development of an Environmental Monitoring Plan, incorporating existing compliance monitoring and supplemental monitoring on water, air, solid waste, worker health and safety, and socioeconomic impacts during the period 1986-1993. Phase I of the project is to produce 10,000 barrels per day of syncrude from oil shale, using the Unishale B process. A summary of compliance and supplemental activities is included in the report. Health monitoring results, safety summaries and a status report of the retorted shale laydown area, with photos, are also given.

  17. Common clay and shale

    USGS Publications Warehouse

    Virta, R.L.

    2011-01-01

    The article discusses the latest developments in the global common clay and shale industry, particularly in the U.S. It claims that common clay and shale is mainly used in the manufacture of heavy clay products like brick, flue tile and sewer pipe. The main producing states in the U.S. include North Carolina, New York and Oklahoma. Among the firms that manufacture clay and shale-based products are Mid America Brick & Structural Clay Products LLC and Boral USA.

  18. Energy from true in situ processing of antrim shale: Extraction trials in an explosively fractured site

    NASA Astrophysics Data System (ADS)

    Vanderploeg, M. L.; Peil, C. A.; Kinkel, C. G.; Pihlaja, R. K.; Murdick, D. A.; Frost, J. R.; Lund, M. M.

    1980-08-01

    Three in situ energy extraction trials were conducted at an oil shale site in Michigan. Here the Antrim shale layer occurs between 1200 and 1400 feet underground. The three trials, lasting 7, 60 and 17 days respectively, were conducted in a formation prepared by explosive fracturing. Ignition energy was generated with a methane burner. Some energy in the form of a dilute fuel gas was recovered in each trial but upon ignition drastic decreases in flow communication occurred between injection and production wells. That problem prevented the planned exploration of techniques which would raise the energy value of the production gas. Upon cool down of the formation after each trial, air permeability tests showed inter-well communication levels returning to near preburn levels. Thermal expansion is the most likely cause of the reduced permeability experienced under retorting conditions.

  19. Explosively produced fracture of oil shale. Progress report, July-September 1982

    SciTech Connect

    Not Available

    1983-02-01

    The Los Alamos National Laboratory is conducting rock fragmentation research in oil shale to develop the blasting and fluid-flow technologies required to prepare a rubble bed for a modified in situ retort. The first section of this report summarizes the rock fragmentation program completed with the cooperation of the Oil Shale Consortium and Science Applications, Inc.; it also details the plans for a joint DOE/Sandia National Laboratories/Los Alamos program based on the results of the Consortium program. In addition, Sec. I describes the explosive engineering tests conducted to evaluate dead-pressing characteristics and to verify the reversal-plane fracture capabilities of the ANFO slurry explosive used in the Consortium program. The second section presents a paper on computer modeling and theory that relates the permeability of fractured rock to percolation theory and statistical crack mechanics.

  20. Mercury isotope fractionation during ore retorting in the Almadén mining district, Spain

    USGS Publications Warehouse

    Gray, John E.; Pribil, Michael J.; Higueras, Pablo L.

    2013-01-01

    Almadén, Spain, is the world's largest mercury (Hg) mining district, which has produced over 250,000 metric tons of Hg representing about 30% of the historical Hg produced worldwide. The objective of this study was to measure Hg isotopic compositions of cinnabar ore, mine waste calcine (retorted ore), elemental Hg (Hg0(L)), and elemental Hg gas (Hg0(g)), to evaluate potential Hg isotopic fractionation. Almadén cinnabar ore δ202Hg varied from − 0.92 to 0.15‰ (mean of − 0.56‰, σ = 0.35‰, n = 7), whereas calcine was isotopically heavier and δ202Hg ranged from − 0.03‰ to 1.01‰ (mean of 0.43‰, σ = 0.44‰, n = 8). The average δ202Hg enrichment of 0.99‰ between cinnabar ore and calcines generated during ore retorting indicated Hg isotopic mass dependent fractionation (MDF). Mass independent fractionation (MIF) was not observed in any of the samples in this study. Laboratory retorting experiments of cinnabar also were carried out to evaluate Hg isotopic fractionation of products generated during retorting such as calcine, Hg0(L), and Hg0(g). Calcine and Hg0(L) generated during these retorting experiments showed an enrichment in δ202Hg of as much as 1.90‰ and 0.67‰, respectively, compared to the original cinnabar ore. The δ202Hg for Hg0(g) generated during the retorting experiments was as much as 1.16‰ isotopically lighter compared to cinnabar, thus, when cinnabar ore was roasted, the resultant calcines formed were isotopically heavier, whereas the Hg0(g) generated was isotopically lighter in Hg isotopes.

  1. Genotoxicity induced by a shale oil byproduct in Chinese hamster cells following metabolic activation

    SciTech Connect

    Okinaka, R.T.; Nickols, J.W.; Chen, D.J.; Strniste, G.F.

    1982-01-01

    A process water obtained from a holding tank during the surface retorting of oil shale has been shown to induce a linear dose response of 100 histidine revertants/sub ..mu../1 in the Ames/Salmonella test. The complex mixture has also previously been shown to induce genotoxicity in mammalian cells following activation by near ultraviolet light and natural sunlight. This report focuses on the effects of a particular oil shale retort process water on cultured Chinese hamster cells following metabolic activation by either rat liver homogenate or lethally irradiated but metabolically competent Syrian hamster embryonic cells. Cytotoxic and mutagenic responses induced by the process water and a fractionated sample from it containing the majority of the mutagenic activity (as assessed by the Salmonella test) were measured under conditions designed to optimally measure the mutagenic potency of the promutagen, benzo(a)pyrene. These results suggest a possible discrepancy in the genotoxic potential of this complex mixture when various methods are utilized to measure its potential.

  2. A novel energy-efficient pyrolysis process: self-pyrolysis of oil shale triggered by topochemical heat in a horizontal fixed bed.

    PubMed

    Sun, You-Hong; Bai, Feng-Tian; Lü, Xiao-Shu; Li, Qiang; Liu, Yu-Min; Guo, Ming-Yi; Guo, Wei; Liu, Bao-Chang

    2015-02-06

    This paper proposes a novel energy-efficient oil shale pyrolysis process triggered by a topochemical reaction that can be applied in horizontal oil shale formations. The process starts by feeding preheated air to oil shale to initiate a topochemical reaction and the onset of self-pyrolysis. As the temperature in the virgin oil shale increases (to 250-300°C), the hot air can be replaced by ambient-temperature air, allowing heat to be released by internal topochemical reactions to complete the pyrolysis. The propagation of fronts formed in this process, the temperature evolution, and the reaction mechanism of oil shale pyrolysis in porous media are discussed and compared with those in a traditional oxygen-free process. The results show that the self-pyrolysis of oil shale can be achieved with the proposed method without any need for external heat. The results also verify that fractured oil shale may be more suitable for underground retorting. Moreover, the gas and liquid products from this method were characterised, and a highly instrumented experimental device designed specifically for this process is described. This study can serve as a reference for new ideas on oil shale in situ pyrolysis processes.

  3. A Novel Energy-Efficient Pyrolysis Process: Self-pyrolysis of Oil Shale Triggered by Topochemical Heat in a Horizontal Fixed Bed

    PubMed Central

    Sun, You-Hong; Bai, Feng-Tian; Lü, Xiao-Shu; Li, Qiang; Liu, Yu-Min; Guo, Ming-Yi; Guo, Wei; Liu, Bao-Chang

    2015-01-01

    This paper proposes a novel energy-efficient oil shale pyrolysis process triggered by a topochemical reaction that can be applied in horizontal oil shale formations. The process starts by feeding preheated air to oil shale to initiate a topochemical reaction and the onset of self-pyrolysis. As the temperature in the virgin oil shale increases (to 250–300°C), the hot air can be replaced by ambient-temperature air, allowing heat to be released by internal topochemical reactions to complete the pyrolysis. The propagation of fronts formed in this process, the temperature evolution, and the reaction mechanism of oil shale pyrolysis in porous media are discussed and compared with those in a traditional oxygen-free process. The results show that the self-pyrolysis of oil shale can be achieved with the proposed method without any need for external heat. The results also verify that fractured oil shale may be more suitable for underground retorting. Moreover, the gas and liquid products from this method were characterised, and a highly instrumented experimental device designed specifically for this process is described. This study can serve as a reference for new ideas on oil shale in situ pyrolysis processes. PMID:25656294

  4. Future of oil shale

    SciTech Connect

    Aspinall, W.N.

    1982-01-01

    A leader in mining legislation and a long-time promoter of the oil-shale industry, Wayne Aspinall predicts that free enterprise can bring successful commercialization of US shale-oil deposits when such development becomes economically competitive. This is preferable to direct government subsidies. A commitment to research activities, pilot plants, and prototype plans must come before commercialization. (DCK)

  5. Borehole Stability Analysis of Horizontal Drilling in Shale Gas Reservoirs

    NASA Astrophysics Data System (ADS)

    Yuan, Jun-Liang; Deng, Jin-Gen; Tan, Qiang; Yu, Bao-Hua; Jin, Xiao-Chun

    2013-09-01

    Serious wellbore instability occurs frequently during horizontal drilling in shale gas reservoirs. The conventional forecast model of in situ stresses is not suitable for wellbore stability analysis in laminated shale gas formations because of the inhomogeneous mechanical properties of shale. In this study, a new prediction method is developed to calculate the in situ stresses in shale formations. The pore pressure near the borehole is heterogeneous along both the radial and tangential directions due to the inhomogeneity in the mechanical properties and permeability. Therefore, the stress state around the wellbore will vary with time after the formation is drained. Besides, based on the experimental results, a failure criterion is verified and applied to determine the strength of Silurian shale in the Sichuan Basin, including the long-term strength of gas shale. Based on this work, horizontal well borehole stability is analyzed by the new in situ stress prediction model. Finally, the results show that the collapse pressure will be underestimated if the conventional model is used in shale gas reservoirs improperly. The collapse pressure of a horizontal well is maximum at dip angle of 45°. The critical mud weight should be increased constantly to prevent borehole collapse if the borehole is exposed for some time.

  6. Creep behavior of Utah oil shale subject to uniaxial loading

    SciTech Connect

    Chong, K.P.; Dana, G.F.; Chen, J.L.

    1982-06-01

    This paper presents results of a study on the creep behavior of Utah oil shale. A Conbel Model 355 pneumatic driven testing machine is used. The set of duplicate test specimens required for creep testing were cut from a single oil shale layer using a wire saw to avoid any surface damage. A rheological model was developed for creep behavior of oil shale as a function of stress level and organic content. Data from creep testing and Fischer assay analyses were used to demonstrate correlation between various stress levels and organic contents for samples taken from the Mahogany Zone of the Parachute Creek Member in Utah's Cowboy Canyon.

  7. Pressurized fluidized-bed hydroretorting of eastern oil shales. Volume 4, Task 5, Operation of PFH on beneficiated shale, Task 6, Environmental data and mitigation analyses and Task 7, Sample procurement, preparation, and characterization: Final report, September 1987--May 1991

    SciTech Connect

    Not Available

    1992-03-01

    The objective of Task 5 (Operation of Pressurized Fluidized-Bed Hydro-Retorting (PFH) on Beneficiated Shale) was to modify the PFH process to facilitate its use for fine-sized, beneficiated Eastern shales. This task was divided into 3 subtasks: Non-Reactive Testing, Reactive Testing, and Data Analysis and Correlations. The potential environment impacts of PFH processing of oil shale must be assessed throughout the development program to ensure that the appropriate technologies are in place to mitigate any adverse effects. The overall objectives of Task 6 (Environmental Data and Mitigation Analyses) were to obtain environmental data relating to PFH and shale beneficiation and to analyze the potential environmental impacts of the integrated PFH process. The task was divided into the following four subtasks. Characterization of Processed Shales (IGT), 6.2. Water Availability and Treatment Studies, 6.3. Heavy Metals Removal and 6.4. PFH Systems Analysis. The objective of Task 7 (Sample Procurement, Preparation, and Characterization) was to procure, prepare, and characterize raw and beneficiated bulk samples of Eastern oil shale for all of the experimental tasks in the program. Accomplishments for these tasks are presented.

  8. Treatment of concentrated industrial wastewaters originating from oil shale and the like by electrolysis polyurethane foam interaction

    DOEpatents

    Tiernan, Joan E.

    1990-01-01

    Highly concentrated and toxic petroleum-based and synthetic fuels wastewaters such as oil shale retort water are treated in a unit treatment process by electrolysis in a reactor containing oleophilic, ionized, open-celled polyurethane foams and subjected to mixing and laminar flow conditions at an average detention time of six hours. Both the polyurethane foams and the foam regenerate solution are re-used. The treatment is a cost-effective process for waste-waters which are not treatable, or are not cost-effectively treatable, by conventional process series.

  9. FRONT ELEVATION OF TELLURIDE IRON WORKS 2.5 BY 4FOOT RETORT, ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    FRONT ELEVATION OF TELLURIDE IRON WORKS 2.5 BY 4-FOOT RETORT, USED TO FLASH MERCURY FROM GOLD. MERCURY VAPOR THEN CONDENSED ON INSIDE OF HOOD AND WAS COLLECTED FOR REUSE. - Shenandoah-Dives Mill, 135 County Road 2, Silverton, San Juan County, CO

  10. 30 CFR 57.22401 - Underground retorts (I-A and I-B mines).

    Code of Federal Regulations, 2014 CFR

    2014-07-01

    ... 30 Mineral Resources 1 2014-07-01 2014-07-01 false Underground retorts (I-A and I-B mines). 57.22401 Section 57.22401 Mineral Resources MINE SAFETY AND HEALTH ADMINISTRATION, DEPARTMENT OF LABOR METAL AND NONMETAL MINE SAFETY AND HEALTH SAFETY AND HEALTH STANDARDS-UNDERGROUND METAL AND...

  11. 30 CFR 57.22401 - Underground retorts (I-A and I-B mines).

    Code of Federal Regulations, 2012 CFR

    2012-07-01

    ... 30 Mineral Resources 1 2012-07-01 2012-07-01 false Underground retorts (I-A and I-B mines). 57.22401 Section 57.22401 Mineral Resources MINE SAFETY AND HEALTH ADMINISTRATION, DEPARTMENT OF LABOR METAL AND NONMETAL MINE SAFETY AND HEALTH SAFETY AND HEALTH STANDARDS-UNDERGROUND METAL AND...

  12. 30 CFR 57.22401 - Underground retorts (I-A and I-B mines).

    Code of Federal Regulations, 2013 CFR

    2013-07-01

    ... 30 Mineral Resources 1 2013-07-01 2013-07-01 false Underground retorts (I-A and I-B mines). 57.22401 Section 57.22401 Mineral Resources MINE SAFETY AND HEALTH ADMINISTRATION, DEPARTMENT OF LABOR METAL AND NONMETAL MINE SAFETY AND HEALTH SAFETY AND HEALTH STANDARDS-UNDERGROUND METAL AND...

  13. 30 CFR 57.22401 - Underground retorts (I-A and I-B mines).

    Code of Federal Regulations, 2011 CFR

    2011-07-01

    ... 30 Mineral Resources 1 2011-07-01 2011-07-01 false Underground retorts (I-A and I-B mines). 57.22401 Section 57.22401 Mineral Resources MINE SAFETY AND HEALTH ADMINISTRATION, DEPARTMENT OF LABOR METAL AND NONMETAL MINE SAFETY AND HEALTH SAFETY AND HEALTH STANDARDS-UNDERGROUND METAL AND...

  14. 30 CFR 57.22401 - Underground retorts (I-A and I-B mines).

    Code of Federal Regulations, 2010 CFR

    2010-07-01

    ... 30 Mineral Resources 1 2010-07-01 2010-07-01 false Underground retorts (I-A and I-B mines). 57.22401 Section 57.22401 Mineral Resources MINE SAFETY AND HEALTH ADMINISTRATION, DEPARTMENT OF LABOR METAL AND NONMETAL MINE SAFETY AND HEALTH SAFETY AND HEALTH STANDARDS-UNDERGROUND METAL AND...

  15. Mercury retorting of calcine waste, contaminated soils and railroad ballast at the Idaho National Egineering Laboratory

    SciTech Connect

    Cotten, G.B.; Rothermel, J.S.; Sherwood, J.; Heath, S.A.; Lo, T.Y.R.

    1996-02-28

    The Idaho National Engineering Laboratory (INEL) has been involved in nuclear reactor research and development for over 40 years. One of the earliest major projects involved the development of a nuclear powered aircraft engine, a long-term venture which used mercury as a shielding medium. Over the course of several years, a significant amount of mercury was spilled along the railroad tracks where the test engines were transported and stored. In addition, experiments with volume reduction of waste through a calcine process employing mercury as a catalyst resulted in mercury contaminated calcine waste. Both the calcine and Test Area North wastes have been identified in Department of Energy Action Memorandums to be retorted, thereby separating the mercury from the various contaminated media. Lockheed Idaho Technologies Company awarded the Mercury Retort contract to ETAS Corporation and assigned Parsons Engineering Science, Inc. to manage the treatment field activities. The mercury retort process entails a mobile unit which consists of four trailer-mounted subsystems requiring electricity, propane, and a water supply. This mobile system demonstrates an effective strategy for retorting waste and generating minimal secondary waste.

  16. Common clay and shale

    USGS Publications Warehouse

    Virta, R.L.

    2000-01-01

    Part of the 1999 Industrial Minerals Review. The clay and shale market in 1999 is reviewed. In the U.S., sales or use of clay and shale increased from 26.4 million st in 1998 to 27.3 million st in 1999, with an estimated 1999 value of production of $143 million. These materials were used to produce structural clay products, lightweight aggregates, cement, and ceramics and refractories. Production statistics for clays and shales and for their uses in 1999 are presented.

  17. Characterization of interim reference shales

    SciTech Connect

    Miknis, F.P.; Sullivan, S.; Mason, G.

    1986-03-01

    Measurements have been made on the chemical and physical properties of two oil shales designated as interim reference oil shales by the Department of Energy. One oil shale is a Green River Formation, Parachute Creek Member, Mahogany Zone Colorado oil shale from the Anvil Points mine and the other is a Clegg Creek Member, New Albany shale from Kentucky. Material balance Fischer assays, kerogen concentrates, carbon aromaticities, thermal properties, and bulk mineralogic properties have been determined for the oil shales. The measured properties of the interim reference shales are comparable to results obtained from previous studies on similar shales. The western interim reference shale has a low carbon aromaticity, high Fischer assay conversion to oil, and a dominant carbonate mineralogy. The eastern interim reference shale has a high carbon aromaticity, low Fischer assay conversion to oil, and a dominant silicate mineralogy. Chemical and physical properties, including ASTM distillations, have been determined for shale oils produced from the interim reference shales. The distillation data were used in conjunction with API correlations to calculate a large number of shale oil properties that are required for computer models such as ASPEN. The experimental determination of many of the shale oil properties was beyond the scope of this study. Therefore, direct comparison between calculated and measured values of many properties could not be made. However, molecular weights of the shale oils were measured. In this case, there was poor agreement between measured molecular weights and those calculated from API and other published correlations. 23 refs., 12 figs., 15 tabs.

  18. Molecular characterization and comparison of shale oils generated by different pyrolysis methods

    USGS Publications Warehouse

    Birdwell, Justin E.; Jin, Jang Mi; Kim, Sunghwan

    2012-01-01

    Shale oils generated using different laboratory pyrolysis methods have been studied using standard oil characterization methods as well as Fourier transform ion cyclotron resonance mass spectrometry (FT-ICR MS) with electrospray ionization (ESI) and atmospheric photoionization (APPI) to assess differences in molecular composition. The pyrolysis oils were generated from samples of the Mahogany zone oil shale of the Eocene Green River Formation collected from outcrops in the Piceance Basin, Colorado, using three pyrolysis systems under conditions relevant to surface and in situ retorting approaches. Significant variations were observed in the shale oils, particularly the degree of conjugation of the constituent molecules and the distribution of nitrogen-containing compound classes. Comparison of FT-ICR MS results to other oil characteristics, such as specific gravity; saturate, aromatic, resin, asphaltene (SARA) distribution; and carbon number distribution determined by gas chromatography, indicated correspondence between higher average double bond equivalence (DBE) values and increasing asphaltene content. The results show that, based on the shale oil DBE distributions, highly conjugated species are enriched in samples produced under low pressure, high temperature conditions, and under high pressure, moderate temperature conditions in the presence of water. We also report, for the first time in any petroleum-like substance, the presence of N4 class compounds based on FT-ICR MS data. Using double bond equivalence and carbon number distributions, structures for the N4 class and other nitrogen-containing compounds are proposed.

  19. Common clay and shale

    USGS Publications Warehouse

    Virta, R.L.

    2004-01-01

    Part of the 2003 industrial minerals review. The legislation, production, and consumption of common clay and shale are discussed. The average prices of the material and outlook for the market are provided.

  20. Pneumoconiosis of shale miners.

    PubMed Central

    Seaton, A; Lamb, D; Brown, W R; Sclare, G; Middleton, W G

    1981-01-01

    Four patients are described in whom pneumoconiosis was diagnosed towards the end of a lifetime's work in shale mines. All developed complicated pneumoconiosis, diagnosed in two cases at necropsy, in one by lobectomy, and in one radiologically. Two of the patients were found at necropsy also to have peripheral squamous lung cancer.The clinical and histological features of the disease resembled the pneumoconioses of coalminers and kaolin workers and the lungs of three of the patients were shown to contain dust composed predominantly of kaolinite, mica, and silica. Shale miners' complicated pneumoconiosis has not previously been described. Although the British shale industry is now defunct, oil production from shale is expanding in other countries, notably the USA. It is suggested that control should be exercised over dust exposure levels in this industry and that epidemiological studies should be carried out to quantify the risks of both pneumoconiosis and bronchial carcinoma. Images PMID:7314011

  1. Common clay and shale

    USGS Publications Warehouse

    Virta, R.L.

    2006-01-01

    At present, 150 companies produce common clay and shale in 41 US states. According to the United States Geological Survey (USGS), domestic production in 2005 reached 24.8 Mt valued at $176 million. In decreasing order by tonnage, the leading producer states include North Carolina, Texas, Alabama, Georgia and Ohio. For the whole year, residential and commercial building construction remained the major market for common clay and shale products such as brick, drain tile, lightweight aggregate, quarry tile and structural tile.

  2. Porosity and permeability of eastern Devonian gas shale

    SciTech Connect

    Soeder, D.J.

    1986-01-01

    High-precision core analysis has been performed on eight samples of Devonian gas shale from the Appalachian Basin. Seven of the core samples consist of the Upper Devonian age Huron Member of the Ohio Shale, six of which came from wells in the Ohio River valley, and the seventh from a well in east-central Kentucky. The eighth core sample consists of Middle Devonian age Marcellus Shale obtained from a well in Morgantown, West Virginia. The core analysis was originally intended to supply accurate input data for Devonian shale numerical reservoir simulation. Unexpectedly, the results have also shown that there are a number of previously unknown factors which influence or control gas production from organic-rich shales of the Appalachian Basin. The presence of petroleum as a mobile liquid phase in the pores of all seven Huron Shale samples effectively limits the gas porosity of this formation to less than 0.2%, and permeability of the rock matrix to gas is less than 0.1 microdarcy at reservoir stress. The Marcellus Shale core, on the other hand, was free of a mobile liquid phase and had a measured gas porosity of approximately 10% under stress with a fairly strong ''adsorption'' component. Permeability to gas (K/sub infinity/ was highly stress-dependent, ranging from about 20 microdarcies at a net stress of 3000 psi down to about 5 microdarcies at a net stress of 6000 psi. The conclusion reached from this study is that Devonian shale in the Appalachian Basin is a considerably more complex natural gas resource than previously thought. Production potential varies widely with geographic location and stratigraphy, just as it does with other gas and oil resources. 15 refs., 8 figs., 3 tabs.

  3. Influence of site-specific geology on oil shale fragmentation experiments at the Colony Mine, Garfield County, Colorado

    SciTech Connect

    Ray, J.M.; Harper, M.D.; Craig, J.L.; Edwards, C.L.

    1982-01-01

    The Los Alamos National Laboratory executed 19 intermediate scale cratering experiments in oil shale at the Colony Mine in Garfield County, Colorado. These experiments have led to a better understanding of fracture characteristics and fragmentation of in situ oil shale by use of a conventional high explosive. Geologic site characterization included detailed mapping, coring, and sample analyses. Site-specific geology was observed to be a major influence on the resulting crater geometry. The joint patterns at the experimental site frequently defined the final crater symmetry. Secondary influences included vugs, lithology changes, and grade fluctuations in the local stratigraphy. Most experiments, in both the rib and floor, were conducted to obtain data to investigate the fragmentation results within the craters. The rubble was screened for fragment-size distributions. Geologic features in proximity to the explosive charge had minimal effect on the rubble due to the overpowering effect of the detonation. However, these same features became more influential on the fracture and rubble characteristics with greater distances from the shothole. Postshot cores revealed a direct relationship between the grade of the oil shale and its susceptibility to fracturing. The Colony Mine experiments have demonstrated the significant role of geology in high explosive/oil shale interaction. It is probable that this role will have to be considered for larger applications to blast patterns and potential problems in retort stability in the future of oil shale development.

  4. Modeling of hydrologic conditions and solute movement in processed oil shale waste embankments under simulated climatic conditions

    SciTech Connect

    Turner, J.P.; Hasfurther, V.

    1992-05-04

    The scope of the research program and the continuation is to study interacting hydrologic, geotechnical, and chemical factors affecting the behavior and disposal of combusted processed oil shale. The research combines bench-scale testing with large scale research sufficient to describe commercial scale embankment behavior. The large scale approach was accomplished by establishing five lysimeters, each 7.3 [times] 3.0 [times] 3.0 m deep, filled with processed oil shale that has been retorted and combusted by the Lurgi-Ruhrgas (Lurgi) process. Approximately 400 tons of Lurgi processed oil shale waste was provided by Rio Blanco Oil Shale Co., Inc. (RBOSC) through a separate cooperative agreement with the University of Wyoming (UW) to carry out this study. Three of the lysimeters were established at the RBOSC Tract C-a in the Piceance Basin of Colorado. Two lysimeters were established in the Environmental Simulation Laboratory (ESL) at UW. The ESL was specifically designed and constructed so that a large range of climatic conditions could be physically applied to the processed oil shale which was filled in the lysimeter cells.

  5. Assessment of In-Place Oil Shale Resources of the Green River Formation, Piceance Basin, Western Colorado

    USGS Publications Warehouse

    Johnson, Ronald C.; Mercier, Tracey J.; Brownfield, Michael E.; Pantea, Michael P.; Self, Jesse G.

    2009-01-01

    The U.S. Geological Survey (USGS) recently completed a reassessment of in-place oil shale resources, regardless of richness, in the Eocene Green River Formation in the Piceance Basin, western Colorado. A considerable amount of oil-yield data has been collected after previous in-place assessments were published, and these data were incorporated into this new assessment. About twice as many oil-yield data points were used, and several additional oil shale intervals were included that were not assessed previously for lack of data. Oil yields are measured using the Fischer assay method. The Fischer assay method is a standardized laboratory test for determining the oil yield from oil shale that has been almost universally used to determine oil yields for Green River Formation oil shales. Fischer assay does not necessarily measure the maximum amount of oil that an oil shale can produce, and there are retorting methods that yield more than the Fischer assay yield. However, the oil yields achieved by other technologies are typically reported as a percentage of the Fischer assay oil yield, and thus Fischer assay is still considered the standard by which other methods are compared.

  6. Parachute Creek Shale Oil Program Environmental Monitoring Program. Quarterly report, fourth quarter, October 1-December 31, 1991

    SciTech Connect

    Not Available

    1992-02-28

    The Energy Security Act of 1980 established a program to provide financial assistance to private industry in the construction and operation of commercial-scale synthetic fuels plants. The Parachute Creek Shale Oil Program is one of four projects awarded financial assistance. The Program agreed to comply with existing environmental monitoring regulations and to develop an Environmental Monitoring Plan (EMP) incorporating supplemental monitoring in the areas of water, air, solid waste, and worker health and safety during the period 1985-1992. These activities are described in a series of quarterly and annual reports. The document contains environmental compliance data collected in the fourth quarter of 1991, contents of reports on compliance data submitted to regulatory agencies, and supplemental analytical results from retorted shale pile runoff water collected following a storm event during the third quarter of 1991.

  7. Unocal Parachute Creek Shale Oil Program Environmental Monitoring Program. Annual report, October 1, 1990-December 31, 1991

    SciTech Connect

    Not Available

    1992-03-31

    The Energy Security Act of 1980 established a program to provide financial assistance to private industry in the construction and operation of commercial-scale synthetic fuels plants. The Parachute Creek Shale Oil Program is one of four projects awarded financial assistance. The Program agreed to comply with existing environmental monitoring regulations and to develop an Environmental Monitoring Plan (EMP) incorporating supplemental monitoring in the areas of water, air, solid waste, and worker health and safety during the period 1985-1992. These activities are described in a series of quarterly and annual reports. The report contains summaries of compliance and supplemental environmental and industrial hygiene and health surveillance monitoring conducted during the period; compliance permits, permit changes, and Notices of Violations discussions; statistical significance of Employee General Health information, medical histories, physical exams, pulmonary functions, clinical tests and demographics; independent audit reports; and a description of retorted shale disposal activities.

  8. Geomechaical Behavior of Shale Rocks Under High Pressure and Temperature

    NASA Astrophysics Data System (ADS)

    Villamor Lora, R.; Ghazanfari, E.

    2014-12-01

    The mechanical properties of shale are demanding parameters for a number of engineering and geomechanical purposes. Borehole stability modeling, geophysics, shale oil and shale gas reservoirs, and underground storage of CO2 in shale formations are some of these potential applications to name a few. The growing interest in these reservoirs, as a source for hydrocarbons production, has resulted in an increasing demand for fundamental rock property data. These rocks are known to be non-linear materials. There are many factors, including induced cracks and their orientation, partial saturation, material heterogeneity and anisotropy, plasticity, strain rate, and temperature that may have an impact on the geomechanical behaviour of these shales.Experimental results and theoretical considerations have shown that the elastic moduli are not single-value, well-defined parameters for a given rock. Finding suitable values for these parameters is of vital importance in many geomechanical applications. In this study, shale heterogeneity and its geomechanical properties are explored through an extensive laboratory experimental program. A series of hydrostatic and triaxial tests were performed in order to evaluate the elasticity, viscoplasticity, yielding and failure response of Marcellus shale samples as a function of pressure and temperature. Additional characterization includes mineralogy, porosity, and permeability measurements. The shale samples were taken from a Marcellus outcrop at State Game Lands 252, located in Lycoming and Union counties, Allenwood, Pennsylvania. Laboratory experiments have shown that creep behaviour is highly sensitive to temperature. Furthermore, the non-linear nature of these rocks reveals interesting behaviour of the elastic moduli highly dependent on stress history of the rock. Results from cyclic triaxial tests point out the different behaviour between 1st-loading and unloading-reloading cycles. Experimental results of these Marcellus shales are

  9. A new laboratory approach to shale analysis using NMR relaxometry

    USGS Publications Warehouse

    Washburn, Kathryn E.; Birdwell, Justin E.; Baez, Luis; Beeney, Ken; Sonnenberg, Steve

    2013-01-01

    Low-field nuclear magnetic resonance (LF-NMR) relaxometry is a non-invasive technique commonly used to assess hydrogen-bearing fluids in petroleum reservoir rocks. Measurements made using LF-NMR provide information on rock porosity, pore-size distributions, and in some cases, fluid types and saturations (Timur, 1967; Kenyon et al., 1986; Straley et al., 1994; Brown, 2001; Jackson, 2001; Kleinberg, 2001; Hurlimann et al., 2002). Recent improvements in LF-NMR instrument electronics have made it possible to apply methods used to measure pore fluids to assess highly viscous and even solid organic phases within reservoir rocks. T1 and T2 relaxation responses behave very differently in solids and liquids; therefore the relationship between these two modes of relaxation can be used to differentiate organic phases in rock samples or to characterize extracted organic materials. Using T1-T2 correlation data, organic components present in shales, such as kerogen and bitumen, can be examined in laboratory relaxometry measurements. In addition, implementation of a solid-echo pulse sequence to refocus T2 relaxation caused by homonuclear dipolar coupling during correlation measurements allows for improved resolution of solid-phase protons. LF-NMR measurements of T1 and T2 relaxation time distributions were carried out on raw oil shale samples from the Eocene Green River Formation and pyrolyzed samples of these shales processed by hydrous pyrolysis and techniques meant to mimic surface and in-situ retorting. Samples processed using the In Situ Simulator approach ranged from bitumen and early oil generation through to depletion of petroleum generating potential. The standard T1-T2 correlation plots revealed distinct peaks representative of solid- and liquid-like organic phases; results on the pyrolyzed shales reflect changes that occurred during thermal processing. The solid-echo T1 and T2 measurements were used to improve assessment of the solid organic phases, specifically

  10. Overpressure generation by load transfer following shale framework weakening due to smectite diagenesis

    USGS Publications Warehouse

    Lahann, R.W.; Swarbrick, R.E.

    2011-01-01

    Basin model studies which have addressed the importance of smectite conversion to illite as a source of overpressure in the Gulf of Mexico have principally relied on a single-shale compaction model and treated the smectite reaction as only a fluid-source term. Recent fluid pressure interpretation and shale petrology studies indicate that conversion of bound water to mobile water, dissolution of load-bearing grains, and increased preferred orientation change the compaction properties of the shale. This results in substantial changes in effective stress and fluid pressure. The resulting fluid pressure can be 1500-3000psi higher than pressures interpreted from models based on shallow compaction trends. Shale diagenesis changes the mineralogy, volume, and orientation of the load-bearing grains in the shale as well as the volume of bound water. This process creates a weaker (more compactable) grain framework. When these changes occur without fluid export from the shale, some of the stress is transferred from the grains onto the fluid. Observed relationships between shale density and calculated effective stress in Gulf of Mexico shelf wells confirm these changes in shale properties with depth. Further, the density-effective stress changes cannot be explained by fluid-expansion or fluid-source processes or by prediagenesis compaction, but are consistent with a dynamic diagenetic modification of the shale mineralogy, texture, and compaction properties during burial. These findings support the incorporation of diagenetic modification of compaction properties as part of the fluid pressure interpretation process. ?? 2011 Blackwell Publishing Ltd.

  11. Energy and process substitution in the frozen-food industry: geothermal energy and the retortable pouch

    SciTech Connect

    Stern, M.W.; Hanemann, W.M.; Eckhouse, K.

    1981-12-01

    An assessment is made of the possibilities of using geothermal energy and an aseptic retortable pouch in the food processing industry. The focus of the study is on the production of frozen broccoli in the Imperial Valley, California. Background information on the current status of the frozen food industry, the nature of geothermal energy as a potential substitute for conventional fossil fuels, and the engineering details of the retortable pouch process are covered. The analytical methodology by which the energy and process substitution were evaluated is described. A four-way comparison of the economics of the frozen product versus the pouched product and conventional fossil fuels versus geothermal energy was performed. A sensitivity analysis for the energy substitution was made and results are given. Results are summarized. (MCW)

  12. Shale: Measurement of thermal properties

    SciTech Connect

    Gilliam, T.M.; Morgan, I.L.

    1987-07-01

    Thermal conductivity and heat capacity measurements were made on samples of Devonian shale, Pierre shale, and oil shale from the Green River Formation. Thermal expansion measurements were made on selected samples of Devonian shale. Measurements were obtained over the temperature range of ambient to 473 K. Average values for thermal conductivity and heat capacity for the samples studied were within two standard deviations of all data over this temperature range. 15 refs., 12 figs., 4 tabs.

  13. Eastern Gas Shales Project

    SciTech Connect

    Koen, A.D.

    1981-05-01

    The Eastern Gas Shales Project (EGSP), the DOE study to obtain reliable estimates of economically recoverable gas from shale formations in the Appalachian basin, has determined that between 20 and 50 TCF of gas can be recovered from the region. The EGSP final report states that the expected (mean) total economically recoverable gas is 20.2 TCF, with a standard deviation of 1.6 TCF, conditional on the use of shooting technology on 160-acre well spacing. If shooting technology is used and 160-acre well spacing maintained a 95% probability exists that the total recoverable gas from Appalachian basin Devonian shale is between 17.06 and 23.34 TCF.

  14. GIS-based geospatial infrastructure of water resource assessment for supporting oil shale development in Piceance Basin of Northwestern Colorado

    NASA Astrophysics Data System (ADS)

    Zhou, Wei; Minnick, Matthew D.; Mattson, Earl D.; Geza, Mengistu; Murray, Kyle E.

    2015-04-01

    Oil shale deposits of the Green River Formation (GRF) in Northwestern Colorado, Southwestern Wyoming, and Northeastern Utah may become one of the first oil shale deposits to be developed in the U.S. because of their richness, accessibility, and extensive prior characterization. Oil shale is an organic-rich fine-grained sedimentary rock that contains significant amounts of kerogen from which liquid hydrocarbons can be produced. Water is needed to retort or extract oil shale at an approximate rate of three volumes of water for every volume of oil produced. Concerns have been raised over the demand and availability of water to produce oil shale, particularly in semiarid regions where water consumption must be limited and optimized to meet demands from other sectors. The economic benefit of oil shale development in this region may have tradeoffs within the local and regional environment. Due to these potential environmental impacts of oil shale development, water usage issues need to be further studied. A basin-wide baseline for oil shale and water resource data is the foundation of the study. This paper focuses on the design and construction of a centralized geospatial infrastructure for managing a large amount of oil shale and water resource related baseline data, and for setting up the frameworks for analytical and numerical models including but not limited to three-dimensional (3D) geologic, energy resource development systems, and surface water models. Such a centralized geospatial infrastructure made it possible to directly generate model inputs from the same database and to indirectly couple the different models through inputs/outputs. Thus ensures consistency of analyses conducted by researchers from different institutions, and help decision makers to balance water budget based on the spatial distribution of the oil shale and water resources, and the spatial variations of geologic, topographic, and hydrogeological characterization of the basin. This endeavor

  15. GIS-based Geospatial Infrastructure of Water Resource Assessment for Supporting Oil Shale Development in Piceance Basin of Northwestern Colorado

    SciTech Connect

    Zhou, Wei; Minnick, Matthew D; Mattson, Earl D; Geza, Mengistu; Murray, Kyle E.

    2015-04-01

    Oil shale deposits of the Green River Formation (GRF) in Northwestern Colorado, Southwestern Wyoming, and Northeastern Utah may become one of the first oil shale deposits to be developed in the U.S. because of their richness, accessibility, and extensive prior characterization. Oil shale is an organic-rich fine-grained sedimentary rock that contains significant amounts of kerogen from which liquid hydrocarbons can be produced. Water is needed to retort or extract oil shale at an approximate rate of three volumes of water for every volume of oil produced. Concerns have been raised over the demand and availability of water to produce oil shale, particularly in semiarid regions where water consumption must be limited and optimized to meet demands from other sectors. The economic benefit of oil shale development in this region may have tradeoffs within the local and regional environment. Due to these potential environmental impacts of oil shale development, water usage issues need to be further studied. A basin-wide baseline for oil shale and water resource data is the foundation of the study. This paper focuses on the design and construction of a centralized geospatial infrastructure for managing a large amount of oil shale and water resource related baseline data, and for setting up the frameworks for analytical and numerical models including but not limited to three-dimensional (3D) geologic, energy resource development systems, and surface water models. Such a centralized geospatial infrastructure made it possible to directly generate model inputs from the same database and to indirectly couple the different models through inputs/outputs. Thus ensures consistency of analyses conducted by researchers from different institutions, and help decision makers to balance water budget based on the spatial distribution of the oil shale and water resources, and the spatial variations of geologic, topographic, and hydrogeological Characterization of the basin. This endeavor

  16. Laboratory measurement and interpretation of nonlinear gas flow in shale

    NASA Astrophysics Data System (ADS)

    Kang, Yili; Chen, Mingjun; Li, Xiangchen; You, Lijun; Yang, Bin

    2015-11-01

    Gas flow mechanisms in shale are urgent to clarify due to the complicated pore structure and low permeability. Core flow experiments were conducted under reservoir net confining stress with samples from the Longmaxi Shale to investigate the characteristics of nonlinear gas flow. Meanwhile, microstructure analyses and gas adsorption experiments are implemented. Experimental results indicate that non-Darcy flow in shale is remarkable and it has a close relationship with pore pressure. It is found that type of gas has a significant influence on permeability measurement and methane is chosen in this work to study the shale gas flow. Gas slippage effect and minimum threshold pressure gradient weaken with the increasing backpressure. It is demonstrated that gas flow regime would be either slip flow or transition flow with certain pore pressure and permeability. Experimental data computations and microstructure analyses confirm that hydraulic radius of flow tubes in shale are mostly less than 100 nm, indicating that there is no micron scale pore or throat which mainly contributes to flow. The results are significant for the study of gas flow in shale, and are beneficial for laboratory investigation of shale permeability.

  17. Stress trajectory and advanced hydraulic-fracture simulations for the Eastern Gas Shales Project. Final report, April 30, 1981-July 30, 1983

    SciTech Connect

    Advani, S.H.; Lee, J.K.

    1983-01-01

    A summary review of hydraulic fracture modeling is given. Advanced hydraulic fracture model formulations and simulation, using the finite element method, are presented. The numerical examples include the determination of fracture width, height, length, and stress intensity factors with the effects of frac fluid properties, layered strata, in situ stresses, and joints. Future model extensions are also recommended. 66 references, 23 figures.

  18. Combustion heater for oil shale

    DOEpatents

    Mallon, Richard G.; Walton, Otis R.; Lewis, Arthur E.; Braun, Robert L.

    1985-01-01

    A combustion heater for oil shale heats particles of spent oil shale containing unburned char by burning the char. A delayed fall is produced by flowing the shale particles down through a stack of downwardly sloped overlapping baffles alternately extending from opposite sides of a vertical column. The delayed fall and flow reversal occurring in passing from each baffle to the next increase the residence time and increase the contact of the oil shale particles with combustion supporting gas flowed across the column to heat the shale to about 650.degree.-700.degree. C. for use as a process heat source.

  19. Combustion heater for oil shale

    DOEpatents

    Mallon, R.; Walton, O.; Lewis, A.E.; Braun, R.

    1983-09-21

    A combustion heater for oil shale heats particles of spent oil shale containing unburned char by burning the char. A delayed fall is produced by flowing the shale particles down through a stack of downwardly sloped overlapping baffles alternately extending from opposite sides of a vertical column. The delayed fall and flow reversal occurring in passing from each baffle to the next increase the residence time and increase the contact of the oil shale particles with combustion supporting gas flowed across the column to heat the shale to about 650 to 700/sup 0/C for use as a process heat source.

  20. Water Availability for Shale Gas Development in Sichuan Basin, China.

    PubMed

    Yu, Mengjun; Weinthal, Erika; Patiño-Echeverri, Dalia; Deshusses, Marc A; Zou, Caineng; Ni, Yunyan; Vengosh, Avner

    2016-03-15

    Unconventional shale gas development holds promise for reducing the predominant consumption of coal and increasing the utilization of natural gas in China. While China possesses some of the most abundant technically recoverable shale gas resources in the world, water availability could still be a limiting factor for hydraulic fracturing operations, in addition to geological, infrastructural, and technological barriers. Here, we project the baseline water availability for the next 15 years in Sichuan Basin, one of the most promising shale gas basins in China. Our projection shows that continued water demand for the domestic sector in Sichuan Basin could result in high to extremely high water stress in certain areas. By simulating shale gas development and using information from current water use for hydraulic fracturing in Sichuan Basin (20,000-30,000 m(3) per well), we project that during the next decade water use for shale gas development could reach 20-30 million m(3)/year, when shale gas well development is projected to be most active. While this volume is negligible relative to the projected overall domestic water use of ∼36 billion m(3)/year, we posit that intensification of hydraulic fracturing and water use might compete with other water utilization in local water-stress areas in Sichuan Basin.

  1. Water Availability for Shale Gas Development in Sichuan Basin, China.

    PubMed

    Yu, Mengjun; Weinthal, Erika; Patiño-Echeverri, Dalia; Deshusses, Marc A; Zou, Caineng; Ni, Yunyan; Vengosh, Avner

    2016-03-15

    Unconventional shale gas development holds promise for reducing the predominant consumption of coal and increasing the utilization of natural gas in China. While China possesses some of the most abundant technically recoverable shale gas resources in the world, water availability could still be a limiting factor for hydraulic fracturing operations, in addition to geological, infrastructural, and technological barriers. Here, we project the baseline water availability for the next 15 years in Sichuan Basin, one of the most promising shale gas basins in China. Our projection shows that continued water demand for the domestic sector in Sichuan Basin could result in high to extremely high water stress in certain areas. By simulating shale gas development and using information from current water use for hydraulic fracturing in Sichuan Basin (20,000-30,000 m(3) per well), we project that during the next decade water use for shale gas development could reach 20-30 million m(3)/year, when shale gas well development is projected to be most active. While this volume is negligible relative to the projected overall domestic water use of ∼36 billion m(3)/year, we posit that intensification of hydraulic fracturing and water use might compete with other water utilization in local water-stress areas in Sichuan Basin. PMID:26881457

  2. Common clay and shale

    USGS Publications Warehouse

    Virta, R.L.

    2003-01-01

    Part of the 2002 industrial minerals review. The production, consumption, and price of shale and common clay in the U.S. during 2002 are discussed. The impact of EPA regulations on brick and structural clay product manufacturers is also outlined.

  3. Common clay and shale

    USGS Publications Warehouse

    Virta, R.L.

    2001-01-01

    Part of the 2000 annual review of the industrial minerals sector. A general overview of the common clay and shale industry is provided. In 2000, U.S. production increased by 5 percent, while sales or use declined to 23.6 Mt. Despite the slowdown in the economy, no major changes are expected for the market.

  4. Oil shale perspectives

    SciTech Connect

    Knutson, C.F.; Dana, G.F.

    1983-03-01

    The worldwide oil shale resources are extremely large. As an example, the calculated recoverable oil from just the Green River Formation in the tri-state area of Colorado-Utah-Wyoming is as large as the estimated ultimate total conventional oil production from the entire world. In addition there are significant resources in other parts of the USA and in other countries. Despite the great potential, the peace of western oil shale development took a general downturn in 1982 because of a combination of factors led by an uncertainty concerning short to intermediate term pricing for crude oil, a lesser demand for petroleum products, and increased projected costs for development. An example is Exxon's announcement that the Exxon/TOSCO multi-billion dollar project would be discontinued and most of its support equipment sold. In the eastern part of the country, Paraho decided not to move its project to Kentucky unless additional financial support could be obtained. On the international front, Brazil and Morocco are actively developing oil shales in their countries, and feasibility and background studies are being conducted in other areas of the world. The industry, from a future commercial development standpoint, and the government, following its policy to promote high-risk, long-range, high-return energy projects, should accelerate their efforts in oil shale research and development. A lead time of 3 to 5 years is necessary from the planning stage to the first barrel of shale oil production. Using a 20,000 bbl/day plant as a minimum goal, modular development of several competing processes and technologies should be conducted in the near future.

  5. Fracturing and brittleness index analyses of shales

    NASA Astrophysics Data System (ADS)

    Barnhoorn, Auke; Primarini, Mutia; Houben, Maartje

    2016-04-01

    The formation of a fracture network in rocks has a crucial control on the flow behaviour of fluids. In addition, an existing network of fractures , influences the propagation of new fractures during e.g. hydraulic fracturing or during a seismic event. Understanding of the type and characteristics of the fracture network that will be formed during e.g. hydraulic fracturing is thus crucial to better predict the outcome of a hydraulic fracturing job. For this, knowledge of the rock properties is crucial. The brittleness index is often used as a rock property that can be used to predict the fracturing behaviour of a rock for e.g. hydraulic fracturing of shales. Various terminologies of the brittleness index (BI1, BI2 and BI3) exist based on mineralogy, elastic constants and stress-strain behaviour (Jin et al., 2014, Jarvie et al., 2007 and Holt et al., 2011). A maximum brittleness index of 1 predicts very good and efficient fracturing behaviour while a minimum brittleness index of 0 predicts a much more ductile shale behaviour. Here, we have performed systematic petrophysical, acoustic and geomechanical analyses on a set of shale samples from Whitby (UK) and we have determined the three different brittleness indices on each sample by performing all the analyses on each of the samples. We show that each of the three brittleness indices are very different for the same sample and as such it can be concluded that the brittleness index is not a good predictor of the fracturing behaviour of shales. The brittleness index based on the acoustic data (BI1) all lie around values of 0.5, while the brittleness index based on the stress strain data (BI2) give an average brittleness index around 0.75, whereas the mineralogy brittleness index (BI3) predict values below 0.2. This shows that by using different estimates of the brittleness index different decisions can be made for hydraulic fracturing. If we would rely on the mineralogy (BI3), the Whitby mudstone is not a suitable

  6. Assessment of potential shale-oil and shale-gas resources in Silurian shales of Jordan, 2014

    USGS Publications Warehouse

    Schenk, Christopher J.; Pitman, Janet K.; Charpentier, Ronald R.; Klett, Timothy R.; Tennyson, Marilyn E.; Mercier, Tracey J.; Nelson, Philip H.; Brownfield, Michael E.; Pawlewicz, Mark J.; Wandrey, Craig J.

    2014-01-01

    Using a geology-based assessment methodology, the U.S. Geological Survey estimated means of 11 million barrels of potential shale-oil and 320 billion cubic feet of shale-gas resources in Silurian shales of Jordan.

  7. Optimization of process conditions for Rohu fish in curry medium in retortable pouches using instrumental and sensory characteristics.

    PubMed

    Majumdar, Ranendra K; Dhar, Bahni; Roy, Deepayan; Saha, Apurba

    2015-09-01

    'Kalia', a popular preparation of Rohu fish, packed in four-layered laminated retort pouch was processed in a steam/air mixture over-pressure retort at 121.1 °C to three different F 0 values of 7, 8 and 9 min. Time-temperature data were collected during heat processing using an Ellab Sterilization Monitoring System. Texture profile such as hardness, springiness, gumminess and chewiness decreased as the F 0 value increased. The L* values decreased whereas a* and b* values increased with increasing F 0 value. Based on the commercial sterility, sensory evaluation, colour and texture profile analysis, F 0 value of 8 min and cook value of 66 min, with a total process time of 41.7 min at 121.1 °C was found satisfactory for the preparation of Rohu fish curry (Kalia) in retort pouches. PMID:26344980

  8. Foamed sand provides improved stimulation results from Devonian Shale

    SciTech Connect

    Strang, D.L.; Norton, J.L.

    1983-11-01

    Generally, water saturations in the Devonian Shale are low. Production records indicate minimal, if any, water in the areas producing gas or gas and oil. This low water saturation appears to be the key to stimulating the shale, especially in the oil-producing areas. The introduction of water in the stimulation fluid appears to reduce the permeability to oil, which is reflected in poorer production. The relative permeability reduction seems to be more of a problem than particle migration or clay swelling and could explain the good initial results from straight nitrogen treatments. However, the lack of a proppant, even with low closure stress, leads to very rapid declines. Water-base stimulation fluids appear to increase water saturation in the Devonian Shale. Use of 90+ quality foam with sand should provide a method of minimizing saturation changes while creating a propped fracture. Initial results indicate this technique provides better sustained production increases in the Devonian Shale. This paper defines areas of production, describes the geology and presents physical data of the Devonian Shale. It also compares results of several types of treatments that have been used in the Devonian Shale. These results indicate 90+ quality foam with sand should provide an improved stimulation technique for this formation.

  9. Modeling of hydrologic conditions and solute movement in processed oil shale waste embankments under simulated climatic conditions. Second quarterly report, January 1, 1992--March 31, 1992

    SciTech Connect

    Turner, J.P.; Hasfurther, V.

    1992-05-04

    The scope of the research program and the continuation is to study interacting hydrologic, geotechnical, and chemical factors affecting the behavior and disposal of combusted processed oil shale. The research combines bench-scale testing with large scale research sufficient to describe commercial scale embankment behavior. The large scale approach was accomplished by establishing five lysimeters, each 7.3 {times} 3.0 {times} 3.0 m deep, filled with processed oil shale that has been retorted and combusted by the Lurgi-Ruhrgas (Lurgi) process. Approximately 400 tons of Lurgi processed oil shale waste was provided by Rio Blanco Oil Shale Co., Inc. (RBOSC) through a separate cooperative agreement with the University of Wyoming (UW) to carry out this study. Three of the lysimeters were established at the RBOSC Tract C-a in the Piceance Basin of Colorado. Two lysimeters were established in the Environmental Simulation Laboratory (ESL) at UW. The ESL was specifically designed and constructed so that a large range of climatic conditions could be physically applied to the processed oil shale which was filled in the lysimeter cells.

  10. Modeling of hydrologic conditions and solute movement in processed oil shale waste embankments under simulated climatic conditions. Annual report, October 1991--September 1992

    SciTech Connect

    Turner, J.P.; Reeves, T.L.; Skinner, Q.D.; Hasfurther, V.

    1992-11-01

    The scope of the original research program and of its continuation is to study interacting hydrologic, geotechnical, and chemical factors affecting the behavior and disposal of combusted processed oil shale. The research combines bench-scale testing with large-scale testing sufficient to describe commercial-scale embankment behavior. The large-scale testing was accomplished by constructing five lysimeters, each 7.3{times}3.0{times}3.0 m deep, filled with processed oil shale that has been retorted and combusted by the Lurgi-Ruhrgas (Lurgi) process (Schmalfield 1975). Approximately 400 tons of Lurgi processed oil shale waste was provided by Rio Blanco Oil Shale Co., Inc. to carry out this study. Three of the lysimeters were established at the RBOSC Tract C-a in the Piceance Basin near Rifle, Colorado. Two lysimeters were established in the Environmental Simulation Laboratory (ESL) at UW. The ESL was specifically designed and constructed so that a large range of climatic conditions could be physically applied to the processed oil shale which was placed in the lysimeter cells. This report discusses and summarizes results from scientific efforts conducted between October 1991 and September 1992 for Fiscal Year 1992.

  11. Parachute Creek Shale Oil Program

    SciTech Connect

    Not Available

    1981-01-01

    This pamphlet describes Union Oil's shale oil project in the Parachute Creek area of Garfield County, Colorado. The oil shale is estimated to contain 1.6 billion barrels of recoverable oil in the high Mahogany zone alone. Primarily a public relations publication, the report presented contains general information on the history of the project and Union Oil's future plans. (JMT)

  12. FLUORINE IN COLORADO OIL SHALE.

    USGS Publications Warehouse

    Dyni, John R.; ,

    1985-01-01

    Oil shale from the lower part of the Eocene Green River Formation in the Piceance Creek Basin, Colorado, averages 0. 13 weight percent fluorine, which is about twice that found in common shales, but is the same as the average amount found in some oil shales from other parts of the world. Some fluorine may reside in fluorapatite; however, limited data suggest that cryolite may be quantitatively more important. To gain a better understanding of the detailed distribution of fluorine in the deeper nahcolite-bearing oil shales, cores were selected for study from two exploratory holes drilled in the northern part of the Piceance Creek Basin where the oil shales reach their maximum thickness and grade.

  13. Petrophysical Properties of Cody, Mowry, Shell Creek, and Thermopolis Shales, Bighorn Basin, Wyoming

    NASA Astrophysics Data System (ADS)

    Nelson, P. H.

    2013-12-01

    the trendline is OT > OSC > OC > OM, that is, the velocity in the Mowry Shale is reduced the least and the velocity in the Thermopolis Shale is reduced the most. Velocity reductions are attributed to increases in pore pressure during burial, caused by the generation and retention of gas, with lithology playing a key role in the amount of reduction. Sonic velocity in the four shale units remains low to the present day, after uplift and erosion of as much as 6,500 ft in the deeper part of the basin and consequent possible reduction from maximum pore pressures reached when strata were more deeply buried. A model combining burial history, the decrease of effective stress with increasing pore pressure, and Bower's model for the dependence of sonic velocity on effective stress is proposed to explain the persistence of low velocity in shale units. Interruptions to compaction gradients associated with gas occurrences and overpressure are observed in correlative strata in other basins in Wyoming, so the general results for shales in the Bighorn Basin established in this paper should be applicable elsewhere.

  14. Favorable conditions noted for Australia shale oil

    SciTech Connect

    Not Available

    1986-09-01

    After brief descriptions of the Rundle, Condor, and Stuart/Kerosene Creek oil shale projects in Queensland, the competitive advantages of oil shale development and the state and federal governments' attitudes towards an oil shale industry in Australia are discussed. It is concluded that Australia is the ideal country in which to start an oil shale industry.

  15. Fire and explosion hazards of oil shale

    SciTech Connect

    Not Available

    1989-01-01

    The US Bureau of Mines publication presents the results of investigations into the fire and explosion hazards of oil shale rocks and dust. Three areas have been examined: the explosibility and ignitability of oil shale dust clouds, the fire hazards of oil shale dust layers on hot surfaces, and the ignitability and extinguishment of oil shale rubble piles. 10 refs., 54 figs., 29 tabs.

  16. Energy from true in situ processing of Antrim Shale: extraction trials in an explosively fractured site

    SciTech Connect

    VanDerPloeg, M.L.; Peil, C.A.; Kinkel, C.G.; Pihlaja, R.K.; Murdick, D.A.; Frost, J.R.; Lund, M.M.

    1980-08-01

    Three in situ energy extraction trials were conducted at The Dow Chemical Company's oil shale site, in Michigan's Sanilac County, near the town of Peck. Here the Antrim shale layer occurs between 1200 and 1400 feet underground. The trials began on October 14, 1979, and ended on April 1, 1980. The three trials, lasting 7, 60 and 17 days respectively, were conducted in a formation prepared by explosive fracturing. Ignition energy was generated with a methane burner. Some energy in the form of a dilute fuel gas (5 to 50 btu/scf) was recovered in each trial but upon ignition drastic decreases in flow communication occurred between injection and production wells. That problem prevented the planned exploration of techniques which would raise the energy value of the production gas. Upon cool down of the formation after each trial, air permeability tests showed inter-well communication levels returning to near preburn levels. Thermal expansion is the most likely cause of the reduced permeability experienced under retorting conditions.

  17. Combustion of Australian spent shales compared

    SciTech Connect

    Not Available

    1986-12-01

    The combustion kinetics of spent oil shales from seven major Australian deposits have been examined using a fluidized bed batch technique. Chemical rate constants were shown to vary between the shales and to be less than extrapolations of data from American spent oil shales. The effective diffusivity also varies widely among the shales. The seven oil shales were from the Condor, Duaringa, Lowmead, Nagoorin, Nagoorin South, Rundle and Stuart deposits in Queensland. Results are briefly described. 1 figure, 1 table.

  18. Carbon sequestration in depleted oil shale deposits

    SciTech Connect

    Burnham, Alan K; Carroll, Susan A

    2014-12-02

    A method and apparatus are described for sequestering carbon dioxide underground by mineralizing the carbon dioxide with coinjected fluids and minerals remaining from the extraction shale oil. In one embodiment, the oil shale of an illite-rich oil shale is heated to pyrolyze the shale underground, and carbon dioxide is provided to the remaining depleted oil shale while at an elevated temperature. Conditions are sufficient to mineralize the carbon dioxide.

  19. A study of wellbore stability in shales including poroelastic, chemical, and thermal effects

    NASA Astrophysics Data System (ADS)

    Chen, Guizhong

    Shale is always a troublesome rock during oil and gas drilling operations. Shale (in)stability has been of great concern in the oil industry for decades. It has also been a costly problem and has perplexed the industry for many years. A better understanding of the wellbore stability mechanism in shales is imperative. The object of this study is to develop a comprehensive model to deal with borehole instability problems in shales. Wellbore stability problems are caused by changes in near wellbore pore pressure and rock stresses. The excess of rock effective stresses over the rock strength can cause collapse (shear) or breakdown (tensile) failure of the drilled formation. This imbalance between the rock stress and rock strength always happens when the in-situ rock is drilled out and is replaced by the drilling fluid. Pore pressure alterations due to osmotic effects are a function of the water activity in the drilling fluid and the membrane efficiency of the shale. In this work, thermo-mechanical stresses coupled with the osmotic contributions are used to compute conditions under which the wellbore becomes unstable. The osmotic contribution is added to the hydraulic potential to form the net driving force of the fluid flow. Changes in pore pressure have been observed in shale experiments. An alteration of the shale strength was also observed when shales are exposed to different drilling fluids. It is necessary to consider shale strength alterations when inspecting the wellbore stability status and determining critical mud weights. Thermal diffusion inside the drilled formation induces additional pore pressure and rock stress changes and consequently affects shale stability. Thermal effects are important because thermal diffusion into shale formations occurs more quickly than hydraulic diffusion and thereby dominates during early times. Rock temperature and pore pressure can be partially decoupled for shale formations. The partially decoupled problem can be solved

  20. Biochemical activities in soil overlying Paraho processed oil shale

    SciTech Connect

    Sorensen, D.L.

    1982-01-01

    Microbial activity development in soil materials placed over processed oil shale is vital to the plant litter decomposition, cycling of nutrients, and soil organic matter accumulation and maintenance. Samples collected in the summers of 1979, 1980, and 1981 from revegetated soil 30-, 61-, and 91-cm deep overlying spent oil shale in the Piceance Basin of northwestern Colorado were assayed for dehydrogenease activity with glucose and without glucose, for phosphatase activity, and for acetylene reduction activity. Initial ammonium and nitrite nitrogen oxidation rates and potential denitrification rates were determined in 1981. Zymogenous dehydrogenase activity, phosphatase activity, nitrogenase activity, potential denitrification rates, and direct microscopic counts were lower in surface soil 30 cm deep, and were frequently lower in surface soil 61 cm deep over processed shale than in a surface-disturbed control area soil. Apparently, microbial activities are stressed in these more shallow replaced soils. Soil 61 cm deep over a coarse-rock capillary barrier separating the soil from the spent shale, frequently had improved biochemical activity. Initial ammonium and nitrite nitrogen oxidation rates were lower in all replaced soils than in the disturbed control soil. Soil core samples taken in 1981 were assayed for dehydrogenase and phosphatase activities, viable bacteria, and viable fungal propagules. In general, microbial activity decreased quickly below the surface. At depths greater than 45 cm, microbial activities were similar in buried spent shale and surface-disturbed control soil.

  1. Hydraulic fracture extending into network in shale: reviewing influence factors and their mechanism.

    PubMed

    Ren, Lan; Zhao, Jinzhou; Hu, Yongquan

    2014-01-01

    Hydraulic fracture in shale reservoir presents complex network propagation, which has essential difference with traditional plane biwing fracture at forming mechanism. Based on the research results of experiments, field fracturing practice, theory analysis, and numerical simulation, the influence factors and their mechanism of hydraulic fracture extending into network in shale have been systematically analyzed and discussed. Research results show that the fracture propagation in shale reservoir is influenced by the geological and the engineering factors, which includes rock mineral composition, rock mechanical properties, horizontal stress field, natural fractures, treating net pressure, fracturing fluid viscosity, and fracturing scale. This study has important theoretical value and practical significance to understand fracture network propagation mechanism in shale reservoir and contributes to improving the science and efficiency of shale reservoir fracturing design. PMID:25032240

  2. Hydraulic Fracture Extending into Network in Shale: Reviewing Influence Factors and Their Mechanism

    PubMed Central

    Ren, Lan; Zhao, Jinzhou; Hu, Yongquan

    2014-01-01

    Hydraulic fracture in shale reservoir presents complex network propagation, which has essential difference with traditional plane biwing fracture at forming mechanism. Based on the research results of experiments, field fracturing practice, theory analysis, and numerical simulation, the influence factors and their mechanism of hydraulic fracture extending into network in shale have been systematically analyzed and discussed. Research results show that the fracture propagation in shale reservoir is influenced by the geological and the engineering factors, which includes rock mineral composition, rock mechanical properties, horizontal stress field, natural fractures, treating net pressure, fracturing fluid viscosity, and fracturing scale. This study has important theoretical value and practical significance to understand fracture network propagation mechanism in shale reservoir and contributes to improving the science and efficiency of shale reservoir fracturing design. PMID:25032240

  3. Cr(VI)/Cr(III) and As(V)/As(III) ratio assessments in Jordanian spent oil shale produced by aerobic combustion and Anaerobic Pyrolysis.

    PubMed

    El-Hasan, Tayel; Szczerba, Wojciech; Buzanich, Günter; Radtke, Martin; Riesemeier, Heinrich; Kersten, Michael

    2011-11-15

    With the increase in the awareness of the public in the environmental impact of oil shale utilization, it is of interest to reveal the mobility of potentially toxic trace elements in spent oil shale. Therefore, the Cr and As oxidation state in a representative Jordanian oil shale sample from the El-Lajjoun area were investigated upon different lab-scale furnace treatments. The anaerobic pyrolysis was performed in a retort flushed by nitrogen gas at temperatures in between 600 and 800 °C (pyrolytic oil shale, POS). The aerobic combustion was simply performed in porcelain cups heated in a muffle furnace for 4 h at temperatures in between 700 and 1000 °C (burned oil shale, BOS). The high loss-on-ignition in the BOS samples of up to 370 g kg(-1) results from both calcium carbonate and organic carbon degradation. The LOI leads to enrichment in the Cr concentrations from 480 mg kg(-1) in the original oil shale up to 675 mg kg(-1) in the ≥ 850 °C BOS samples. Arsenic concentrations were not much elevated beyond that in the average shale standard (13 mg kg(-1)). Synchrotron-based X-ray absorption near-edge structure (XANES) analysis revealed that within the original oil shale the oxidation states of Cr and As were lower than after its aerobic combustion. Cr(VI) increased from 0% in the untreated or pyrolyzed oil shale up to 60% in the BOS ash combusted at 850 °C, while As(V) increased from 64% in the original oil shale up to 100% in the BOS ash at 700 °C. No Cr was released from original oil shale and POS products by the European compliance leaching test CEN/TC 292 EN 12457-1 (1:2 solid/water ratio, 24 h shaking), whereas leachates from BOS samples showed Cr release in the order of one mmol L(-1). The leachable Cr content is dominated by chromate as revealed by catalytic adsorptive stripping voltammetry (CAdSV) which could cause harmful contamination of surface and groundwater in the semiarid environment of Jordan.

  4. Cr(VI)/Cr(III) and As(V)/As(III) ratio assessments in Jordanian spent oil shale produced by aerobic combustion and Anaerobic Pyrolysis.

    PubMed

    El-Hasan, Tayel; Szczerba, Wojciech; Buzanich, Günter; Radtke, Martin; Riesemeier, Heinrich; Kersten, Michael

    2011-11-15

    With the increase in the awareness of the public in the environmental impact of oil shale utilization, it is of interest to reveal the mobility of potentially toxic trace elements in spent oil shale. Therefore, the Cr and As oxidation state in a representative Jordanian oil shale sample from the El-Lajjoun area were investigated upon different lab-scale furnace treatments. The anaerobic pyrolysis was performed in a retort flushed by nitrogen gas at temperatures in between 600 and 800 °C (pyrolytic oil shale, POS). The aerobic combustion was simply performed in porcelain cups heated in a muffle furnace for 4 h at temperatures in between 700 and 1000 °C (burned oil shale, BOS). The high loss-on-ignition in the BOS samples of up to 370 g kg(-1) results from both calcium carbonate and organic carbon degradation. The LOI leads to enrichment in the Cr concentrations from 480 mg kg(-1) in the original oil shale up to 675 mg kg(-1) in the ≥ 850 °C BOS samples. Arsenic concentrations were not much elevated beyond that in the average shale standard (13 mg kg(-1)). Synchrotron-based X-ray absorption near-edge structure (XANES) analysis revealed that within the original oil shale the oxidation states of Cr and As were lower than after its aerobic combustion. Cr(VI) increased from 0% in the untreated or pyrolyzed oil shale up to 60% in the BOS ash combusted at 850 °C, while As(V) increased from 64% in the original oil shale up to 100% in the BOS ash at 700 °C. No Cr was released from original oil shale and POS products by the European compliance leaching test CEN/TC 292 EN 12457-1 (1:2 solid/water ratio, 24 h shaking), whereas leachates from BOS samples showed Cr release in the order of one mmol L(-1). The leachable Cr content is dominated by chromate as revealed by catalytic adsorptive stripping voltammetry (CAdSV) which could cause harmful contamination of surface and groundwater in the semiarid environment of Jordan. PMID:21970732

  5. Task 38 - commercial mercury remediation demonstrations: Thermal retorting and physical separation/chemical leaching. Topical report, December 1, 1994--June 30, 1996

    SciTech Connect

    Charlton, D.S.; Fraley, R.H.; Stepan, D.J.

    1998-12-31

    Results are presented on the demonstration of two commercial technologies for the removal of mercury from soils found at natural gas metering sites. Technologies include a thermal retorting process and a combination of separation, leaching, and electrokinetic separation process.

  6. Mathematical modelling of anisotropy of illite-rich shale

    USGS Publications Warehouse

    Chesnokov, E.M.; Tiwary, D.K.; Bayuk, I.O.; Sparkman, M.A.; Brown, R.L.

    2009-01-01

    The estimation of illite-rich shale anisotropy to account for the alignment of clays and gas- or brine-filled cracks is presented via mathematical modelling. Such estimation requires analysis to interpret the dominance of one effect over another. This knowledge can help to evaluate the permeability in the unconventional reservoir, stress orientation, and the seal capacity for the conventional reservoir. Effective media modelling is used to predict the elastic properties of the illite-rich shale and to identify the dominant contributions to the shale anisotropy. We consider two principal reasons of the shale anisotropy: orientation of clay platelets and orientation of fluid-filled cracks. In reality, both of these two factors affect the shale anisotropy. The goal of this study is, first, to separately analyse the effect of these two factors to reveal the specific features in P- and S-wave velocity behaviour typical of each of the factors, and, then, consider a combined effect of the factors when the cracks are horizontally or vertically aligned. To do this, we construct four models of shale. The behaviour of P- and S-wave velocities is analysed when gas- and water-filled cracks embedded in a host matrix are randomly oriented, or horizontally or vertically aligned. The host matrix can be either isotropic or anisotropic (of VTI symmetry). In such a modelling, we use published data on mineralogy and clay platelet alignment along with other micromechanical measurements. In the model, where the host matrix is isotropic, the presence of a singularity point (when the difference VS1 - VS2 changes its sign) in shear wave velocities is an indicator of brine-filled aligned cracks. In the model with the VTI host matrix and horizontally aligned cracks filled with gas, an increase in their volume concentration leads to that the azimuth at which the singularity is observed moves toward the symmetry axis. In this case, if the clay content is small (around 20 per cent), the

  7. USAF shale oil program status

    NASA Technical Reports Server (NTRS)

    Delaney, C. L.

    1984-01-01

    The test and evaluation program on shale derived fuel being conducted by the Air Force is intended to accomplish the minimum amount of testing necessary to assure both the safe use of shale oil derived turbine fuels in operational USAF aircraft and its compatibility with USAF handling systems. This program, which was designed to take advantage of existing R&D testing programs, began in 1981. However, due to a problem in acquiring the necessary fuel, the testing program was suspended until July 1983 when an additional sample of shale derived fuel was received. Tentatively, the Air Force is planning to make three relatively minor revisions to the procurement specifications requirements for the production shale derived fuel. These are: (1) Aromatic Contest (min) - 9% (by volume); (2) Nitrogen (max - 20 ppm by weight); and (3) Antioxidants - 9.1 g/100 gal (U.S.)

  8. Optimization of processing conditions for the sterilization of retorted short-rib patties using the response surface methodology.

    PubMed

    Choi, Su-Hee; Cheigh, Chan-Ick; Chung, Myong-Soo

    2013-05-01

    The aim of this study was to determine the optimum sterilization conditions for short-rib patties in retort trays by considering microbiological safety, nutritive value, sensory characteristics, and textural properties. In total, 27 sterilization conditions with various temperatures, times, and processing methods were tested using a 3(3) factorial design. The response surface methodology (RSM) and contour analysis were applied to find the optimum sterilization conditions for the patties. Quality attributes were significantly affected by the sterilization temperature, time, and processing method. From RSM and contour analysis, the final optimum sterilization condition of the patties that simultaneously satisfied all specifications was determined to be 119.4°C for 18.55min using a water-cascading rotary mode. The findings of the present study suggest that using optimized sterilization conditions will improve the microbial safety, sensory attributes, and nutritional retention for retorted short-rib patties.

  9. Impact of ductility on hydraulic fracturing in shales

    NASA Astrophysics Data System (ADS)

    MacMinn, Chris; Auton, Lucy

    2016-04-01

    Hydraulic fracturing is a method for extracting natural gas and oil from low-permeability rocks such as shale via the high-pressure injection of fluid into the bulk of the rock. The goal is to initiate and propagate fractures that will provide hydraulic access deeper into the reservoir, enabling gas or oil to be collected from a larger region of the rock. Fracture is the tensile failure of a brittle material upon reaching a threshold tensile stress, but some shales have a high clay content and may yield plastically before fracturing. Plastic deformation is the shear failure of a ductile material, during which stress relaxes through irreversible rearrangements of the particles of the material. Here, we investigate the impact of the ductility of shales on hydraulic fracturing. We first consider a simple, axisymmetric model for radially outward fluid injection from a wellbore into a ductile porous rock. We use this model to show that plastic deformation greatly reduces the maximum tensile stress, and that this maximum stress does not always occur at the wellbore. We then complement these results with laboratory experiments in an analogue system, and with numerical simulations based on the discrete element method (DEM), both of which suggest that ductile failure can indeed dramatically change the resulting deformation pattern. These results imply that hydraulic fracturing may fail in ductile rocks, or that the required injection rate for fracking may be much larger than the rate predicted from models that assume purely elastic mechanical behavior.

  10. Impact of ductility on hydraulic fracturing in shales

    NASA Astrophysics Data System (ADS)

    Auton, Lucy; MacMinn, Chris

    2015-11-01

    Hydraulic fracturing is a method for extracting natural gas and oil from low-permeability rocks such as shale via the injection of fluid at high pressure. This creates fractures in the rock, providing hydraulic access deeper into the reservoir and enabling gas to be collected from a larger region of the rock. Fracture is the tensile failure of a brittle material upon reaching a threshold tensile stress, but some shales have a high clay content and may yield plastically before fracturing. Plastic deformation is the shear failure of a ductile material, during which stress relaxes through irreversible rearrangements of the particles of the material. Here, we investigate the impact of the ductility of shales on hydraulic fracturing. We consider a simple, axisymmetric model for radially outward fluid injection from a wellbore into a ductile porous rock. We solve the model semi-analytically at steady state, and numerically in general. We find that plastic deformation greatly reduces the maximum tensile stress, and that this maximum stress does not always occur at the wellbore. These results imply that hydraulic fracturing may fail in ductile rocks, or that the required injection rate for fracking may be much larger than the rate predicted from purely elastic models.

  11. Mixed metal hydroxide mud improves drilling in unstable shales

    SciTech Connect

    Sparling, D.P. ); Williamson, D. )

    1991-06-10

    A mixed metal hydroxide (MMH) mud reduced some of the hole problems common to offset wells in the Arkoma basin. By specially engineering the MMH rheology, cuttings removal efficiency increased, and well bore problems were minimized. Wells drilled in the Arkoma basin frequently have experienced problems associated with hole instability: excessive reaming, stuck pipe, packing off, and difficulty in obtaining open hole logs. These problems often occur in the massive shale intervals of Atokan age. The causes of such problems are generally thought to be related to the dissolution of the reactive shales and clays in the Atoka interval, particularly along microfractures created by the tectonic stresses associated with overthrust environment. There exist insufficient data regarding the borehole stress states, primarily the minimum and maximum horizontal stresses. It is also possible that shear failure at the borehole wall is a result of the stress imbalances. In this area, wells are frequently air-drilled to 5,000-8,000 ft, resulting in significant borehole enlargement, which compounds the problems. Operators typically approach the problem in two ways. Oil muds are used worldwide to reduce the trouble time associated with shales. They have been particularly successful in the Arkoma basin for over 25 years.

  12. Denitrification in marine shales in northeastern Colorado

    USGS Publications Warehouse

    McMahon, P.B.; Böhlke, J.K.; Bruce, B.W.

    1999-01-01

    Parts of the South Platte River alluvial aquifer in northeastern Colorado are underlain by the Pierre Shale, a marine deposit of Late Cretaceous age that is <1000 m thick. Ground water in the aquifer is contaminated with NO3/-, and the shale contains abundant potential electron donors for denitrification in the forms of organic carbon and sulfide minerals. Nested piezometers were sampled, pore water was squeezed from cores of shale, and an injection test was conducted to determine if denitrification in the shale was a sink for alluvial NO3/- and to measure denitrification rates in the shale. Measured values of NO3/-, N2, NH4/+, ??15[NO3/-], ??15N[N2], and ??15N[NH4/+] in the alluvial and shale pore water indicated that denitrification in the shale was a sink for alluvial NO3/-. Chemical gradients, reaction rate constants, and hydraulic head data indicated that denitrification in the shale was limited by the slow rate of NO3/- transport (possibly by diffusion) into the shale. The apparent in situ first-order rate constant for denitrification in the shale based on diffusion calculations was of the order of 0.04-0.4 yr-1, whereas the potential rate constant in the shale based on injection tests was of the order of 60 yr-1. Chemical data and mass balance calculations indicate that organic carbon was the primary electron donor for denitrification in the shale during the injection test, and ferrous iron was a minor electron donor in the process. Flux calculations for the conditions encountered at the site indicate that denitrification in the shale could remove only a small fraction of the annual agricultural NO3/- input to the alluvial aquifer. However, the relatively large potential first-order rate constant for denitrification in the shale indicated that the percentage of NO3/- uptake by the shale could be considerably larger in areas where NO3/- is transported more rapidly into the shale by advection.

  13. Applications of acoustic measurements in shale stability research

    NASA Astrophysics Data System (ADS)

    Davidson, James Alexander

    Shales make up over 75% of the formations encountered during oil and gas drilling operations. Shale related problems cost the industry in excess of $500 million per year. Hole washouts, wall sloughing and hole collapse can cause the drill pipe to become stuck, resulting in costly delays or the complete loss of the hole. Invasion by water from the drilling fluids resulting from chemical potential gradients is believed to be the major cause of shale instability. Increases in water content decrease shale strength. Acoustic measurements are routinely used to estimate the values of various mechanical properties of rocks. Advances in technology have made it possible to make acoustic measurements during drilling operations. Data from pulse-echo transducers is used to estimate the borehole diameter, and data from transmitter receiver pairs is used to determine the velocity of sound through the formations. This study was undertaken to develop methods to use such transducers to monitor changes in the mechanical properties of shales during drilling operations. If the onset of instability can be identified, changes in the drilling fluid chemistry or casing program can be made to avert costly wellbore failures. Experiments were conducted to study the changes in shale properties with water content. Outcrop samples as well as subsurface shales from oil wells were used. Measurements were made at surface and simulated downhole stress conditions. Significant changes in the mechanical properties were found to occur with small changes in the water content. Problems with the preservation and handling procedures that have been routinely used over the years were identified. One of the major problems has been the incomplete removal of entrapped air from conventionally prepared samples. Methods to identify the presence of air in laboratory samples have been developed as well as improved preparation procedures to minimize air entrapment. Transient phenomena occurring within the samples

  14. Maquoketa Shale Caprock Integrity Evaluation

    SciTech Connect

    Leetaru, Hannes

    2014-09-30

    The Knox Project objective is to evaluate the potential of formations within the Cambrian-Ordovician strata above the Mt. Simon Sandstone (St. Peter Sandstone and Potosi Dolomite) as potential targets for carbon dioxide (CO2) sequestration in the Illinois and Michigan Basins. The suitability of the St. Peter Sandstone and Potosi Dolomite to serve as reservoirs for CO2 sequestration is discussed in separate reports. In this report the data gathered from the Knox project, the Illinois Basin – Decatur Project (IBDP) and Illinois Industrial Carbon Capture and Sequestration project (IL-ICCS) are used to make some conclusions about the suitability of the Maquoketa shale as a confining layer for CO2 sequestration. These conclusions are then upscaled to basin-wide inferences based on regional knowledge. Data and interpretations (stratigraphic, petrophysical, fractures, geochemical, risk, seismic) applicable to the Maquoketa Shale from the above mentioned projects was inventoried and summarized. Based on the analysis of these data and interpretations, the Maquoketa Shale is considered to be an effective caprock for a CO2 injection project in either the Potosi Dolomite or St. Peter Sandstone because it has a suitable thickness (~200ft. ~61m), advantageous petrophysical properties (low effective porosity and low permeability), favorable geomechanical properties, an absence of observable fractures and is regionally extensive. Because it is unlikely that CO2 would migrate upward through the Maquoketa Shale, CO2, impact to above lying fresh water aquifers is unlikely. Furthermore, the observations indicate that CO2 injected into the St. Peter Sandstone or Potosi Dolomite may never even migrate up into the Maquoketa Shale at a high enough concentrations or pressure to threaten the integrity of the caprock. Site specific conclusions were reached by unifying the data and conclusions from the IBDP, ICCS and the Knox projects. In the Illinois Basin, as one looks further away from

  15. Effects of strain rate and confining pressure on the deformation and failure of shale

    SciTech Connect

    Cook, J.M. ); Sheppard, M.C. ); Houwen, O.H. )

    1991-06-01

    Previous work on shale mechanical properties has focused on the slow deformation rates appropriate to wellbore deformation. Deformation of shale under a drill bit occurs at a very high rate, and the failure properties of the rock under these conditions are crucial in determining bit performance and in extracting lithology and pore-pressure information from drilling parameters. Triaxial tests were performed on two nonswelling shales under a wide range of strain rates and confining and pore pressures. At low strain rates, when fluid is relatively free to move within the shale, shale deformation and failure are governed by effective stress or pressure (i.e., total confining pressure minus pore pressure), as is the case for ordinary rock. If the pore pressure in the shale is high, increasing the strain rate beyond about 0.1%/sec causes large increases in the strength and ductility of the shale. Total pressure begins to influence the strength. At high stain rates, the influence of effective pressure decreases, except when it is very low (i.e., when pore pressure is very high); ductility then rises rapidly. This behavior is opposite that expected in ordinary rocks. This paper briefly discusses the reasons for these phenomena and their impact on wellbore and drilling problems.

  16. Processing and storage of restructured surimi stew product in retortable pouches.

    PubMed

    Hema, K; Shakila, R Jeya; Shanmugam, S A; Jeevithan, E

    2015-03-01

    Restructured surimi gel product was prepared using short nosed white tripod (Triacanthus brevirosterus) with egg white as additive at 1 %. Heat setting was done initially at 45 °C for 30 min followed by heat processing 90 °C for 45 min. Restructured surimi gel in stew was standardized using four most popular recipes available in local cuisine based on the sensory acceptance and the Kerala fish stew was considered best. Restructured surimi gel in Kerala fish stew was then heat processed in 4 ply laminated retort pouch of dimension 150× 200 mm, at 15 psi gauge pressure for varying time duration and the Fo values ranged from 13.10 to 22.58 min. Products examined of their organoleptic and microbial qualities showed those processed with Fo value of 13.10 min was acceptable with excellent eating quality with no fishy flavour and was microbial sterile until the storage period of 6 months.

  17. Developing the Geokinetics/Department of Energy horizontal in situ retorting process. Final report

    SciTech Connect

    Lekas, M.A.

    1985-06-01

    This report summarizes work performed under a cooperative agreement between Geokinetics Inc., and the US Department of Energy, spanning on eight year period. A large body of experimental data was generated which has been previously reported in a series of published and unpublished reports, as indicated in Chapter VII. The report summarizes research work performed from April of 1975 to August 15, 1985, but emphasizes data generated during the final three years of the project, when five large retorts were tested. The report draws conclusions based upon the total program, including work performed by Geokinetics prior to entering into the Cooperative Agreement, and presents the initial parameters useful for scaleup and design of a commercial scale operation, including data useful for assessing the environmental impacts and criteria for mitigation of such impacts. Specific details concerning the various aspects of the program may be obtained from the many previous reports that have been generated from the date of project initiation. A list of these reports is presented in Chapter VII. 28 refs., 11 figs., 10 tabs.

  18. Health effects research in oil shale development

    SciTech Connect

    Schultz, T.W.; Witschi, H.; Smith, L.H.; Haschek, W.M.; Holland, J.M.; Epler, J.L.; Fry, R.J.M.; Rao, T.K.; Larimer, F.W.; Dumont, J.N.

    1981-11-01

    This task includes the testing of primary effluents and products of oil shales to determine the risk posed to the shale oil industrial worker as well as consumer. Paraho/Sohio Shale Oil was found to be mutagenic in the Ames assay and confirmed in the yeast system. After chemical fractionation of the crude shale oil, it was found that the mutagenic activity was contributed by the organic constituents of the basic and neutral fractions. Hydrotreatment of the shale oil abolished the detectable mutagenic activity and also reduced the cytotoxicity as measured in cellular systems. Refined shale oil, jet fuel, and diesel fuel marine samples were not mutagenic. The samples rank for their mutagenic activity as coal oils > shale oil > natural petroleum crudes and only qualitatively agree with carcinogenic activity. Acute toxicity of Paraho Crude Shale Oil and its upgraded derivatives does not appear to be a problem of immediate concern. The data obtained in the lung adenoma bioassay suggest that Crude Shale Oil has tumorigenic potential. Paraho shale oil is carcinogenic in mouse skin. Hydrotreatment reduces but does not eliminate skin carcinogenicity and appreciable carcinogenic activity remains in the residue material. Kidney injury was noted following chronic dermal exposure to shale and petroleum derived middle distillates.

  19. Numerical Investigation into the Influence of Bedding Plane on Hydraulic Fracture Network Propagation in Shale Formations

    NASA Astrophysics Data System (ADS)

    Yushi, Zou; Xinfang, Ma; Shicheng, Zhang; Tong, Zhou; Han, Li

    2016-09-01

    Shale formations are often characterized by low matrix permeability and contain numerous bedding planes (BPs) and natural fractures (NFs). Massive hydraulic fracturing is an important technology for the economic development of shale formations in which a large-scale hydraulic fracture network (HFN) is generated for hydrocarbon flow. In this study, HFN propagation is numerically investigated in a horizontally layered and naturally fractured shale formation by using a newly developed complex fracturing model based on the 3D discrete element method. In this model, a succession of continuous horizontal BP interfaces and vertical NFs is explicitly represented and a shale matrix block is considered impermeable, transversely isotropic, and linearly elastic. A series of simulations is performed to illustrate the influence of anisotropy, associated with the presence of BPs, on the HFN propagation geometry in shale formations. Modeling results reveal that the presence of BP interfaces increases the injection pressure during fracturing. HF deflection into a BP interface tends to occur under high strength and elastic anisotropy as well as in low vertical stress anisotropy conditions, which generate a T-shaped or horizontal fracture. Opened BP interfaces may limit the growth of the fracture upward and downward, resulting in a very low stimulated thickness. However, the opened BP interfaces favor fracture complexity because of the improved connection between HFs and NFs horizontally under moderate vertical stress anisotropy. This study may help predict the HF growth geometry and optimize the fracturing treatment designs in shale formations with complex depositional heterogeneity.

  20. The Influence of Shales on Slope Instability

    NASA Astrophysics Data System (ADS)

    Stead, Doug

    2016-02-01

    Shales play a major role in the stability of slopes, both natural and engineered. This paper attempts to provide a review of the state-of-the-art in shale slope stability. The complexities of shale terminology and classification are first reviewed followed by a brief discussion of the important physical and mechanical properties of relevance to shale slope stability. The varied mechanisms of shale slope stability are outlined and their importance highlighted by reference to international shale slope failures. Stability analysis and modelling of anisotropic rock slope masses are briefly discussed and the potential role of brittle rock fracture and damage highlighted. A short review of shale slopes in open pits is presented.

  1. Geochemistry of Graywackes and Shales.

    PubMed

    Weber, J N

    1960-03-01

    Sixty-nine graywackes and 33 shales were analyzed spectrographically for 14 minor elements to illustrate the variation of composition within a graywacke bed, between beds in one section, between sections, and between formations. Analyses of several fractions of a graywacke indicate what each contributes chemically to the rock. PMID:17807444

  2. On wettability of shale rocks.

    PubMed

    Roshan, H; Al-Yaseri, A Z; Sarmadivaleh, M; Iglauer, S

    2016-08-01

    The low recovery of hydraulic fracturing fluid in unconventional shale reservoirs has been in the centre of attention from both technical and environmental perspectives in the last decade. One explanation for the loss of hydraulic fracturing fluid is fluid uptake by the shale matrix; where capillarity is the dominant process controlling this uptake. Detailed understanding of the rock wettability is thus an essential step in analysis of loss of the hydraulic fracturing fluid in shale reservoirs, especially at reservoir conditions. We therefore performed a suit of contact angle measurements on a shale sample with oil and aqueous ionic solutions, and tested the influence of different ion types (NaCl, KCl, MgCl2, CaCl2), concentrations (0.1, 0.5 and 1M), pressures (0.1, 10 and 20MPa) and temperatures (35 and 70°C). Furthermore, a physical model was developed based on the diffuse double layer theory to provide a framework for the observed experimental data. Our results show that the water contact angle for bivalent ions is larger than for monovalent ions; and that the contact angle (of both oil and different aqueous ionic solutions) increases with increase in pressure and/or temperature; these increases are more pronounced at higher ionic concentrations. Finally, the developed model correctly predicted the influence of each tested variable on contact angle. Knowing contact angle and therefore wettability, the contribution of the capillary process in terms of water uptake into shale rocks and the possible impairment of hydrocarbon production due to such uptake can be quantified.

  3. On wettability of shale rocks.

    PubMed

    Roshan, H; Al-Yaseri, A Z; Sarmadivaleh, M; Iglauer, S

    2016-08-01

    The low recovery of hydraulic fracturing fluid in unconventional shale reservoirs has been in the centre of attention from both technical and environmental perspectives in the last decade. One explanation for the loss of hydraulic fracturing fluid is fluid uptake by the shale matrix; where capillarity is the dominant process controlling this uptake. Detailed understanding of the rock wettability is thus an essential step in analysis of loss of the hydraulic fracturing fluid in shale reservoirs, especially at reservoir conditions. We therefore performed a suit of contact angle measurements on a shale sample with oil and aqueous ionic solutions, and tested the influence of different ion types (NaCl, KCl, MgCl2, CaCl2), concentrations (0.1, 0.5 and 1M), pressures (0.1, 10 and 20MPa) and temperatures (35 and 70°C). Furthermore, a physical model was developed based on the diffuse double layer theory to provide a framework for the observed experimental data. Our results show that the water contact angle for bivalent ions is larger than for monovalent ions; and that the contact angle (of both oil and different aqueous ionic solutions) increases with increase in pressure and/or temperature; these increases are more pronounced at higher ionic concentrations. Finally, the developed model correctly predicted the influence of each tested variable on contact angle. Knowing contact angle and therefore wettability, the contribution of the capillary process in terms of water uptake into shale rocks and the possible impairment of hydrocarbon production due to such uptake can be quantified. PMID:27156090

  4. Oil shale, shale oil, shale gas and non-conventional hydrocarbons

    NASA Astrophysics Data System (ADS)

    Clerici, A.; Alimonti, G.

    2015-08-01

    In recent years there has been a world "revolution" in the field of unconventional hydrocarbon reserves, which goes by the name of "shale gas", gas contained inside clay sediments micropores. Shale gas finds particular development in the United States, which are now independent of imports and see a price reduction to less than one third of that in Europe. With the high oil prices, in addition to the non-conventional gas also "oil shales" (fine-grained sedimentary rocks that contain a large amount of organic material to be used both to be directly burned or to extract liquid fuels which go under the name of shale oil), extra heavy oils and bitumen are becoming an industrial reality. Both unconventional gas and oil reserves far exceed in the world the conventional oil and gas reserves, subverting the theory of fossil fuels scarcity. Values and location of these new fossil reserves in different countries and their production by comparison with conventional resources are presented. In view of the clear advantages of unconventional fossil resources, the potential environmental risks associated with their extraction and processing are also highlighted.

  5. Pore Pressure prediction in shale gas reservoirs using neural network and fuzzy logic with an application to Barnett Shale.

    NASA Astrophysics Data System (ADS)

    Aliouane, Leila; Ouadfeul, Sid-Ali; Boudella, Amar

    2015-04-01

    The main goal of the proposed idea is to use the artificial intelligence such as the neural network and fuzzy logic to predict the pore pressure in shale gas reservoirs. Pore pressure is a very important parameter that will be used or estimation of effective stress. This last is used to resolve well-bore stability problems, failure plan identification from Mohr-Coulomb circle and sweet spots identification. Many models have been proposed to estimate the pore pressure from well-logs data; we can cite for example the equivalent depth model, the horizontal model for undercompaction called the Eaton's model…etc. All these models require a continuous measurement of the slowness of the primary wave, some thing that is not easy during well-logs data acquisition in shale gas formtions. Here, we suggest the use the fuzzy logic and the multilayer perceptron neural network to predict the pore pressure in two horizontal wells drilled in the lower Barnett shale formation. The first horizontal well is used for the training of the fuzzy set and the multilayer perecptron, the input is the natural gamma ray, the neutron porosity, the slowness of the compression and shear wave, however the desired output is the estimated pore pressure using Eaton's model. Data of another horizontal well are used for generalization. Obtained results clearly show the power of the fuzzy logic system than the multilayer perceptron neural network machine to predict the pore pressure in shale gas reservoirs. Keywords: artificial intelligence, fuzzy logic, pore pressure, multilayer perecptron, Barnett shale.

  6. Geomechanical and anisotropic acoustic properties of Lower Jurassic Posidonia shales from Whitby (UK)

    NASA Astrophysics Data System (ADS)

    Zhubayev, Alimzhan; Houben, Maartje; Smeulders, David; Barnhoorn, Auke

    2014-05-01

    The Posidonia Shale Formation (PSF) is one of the possible resource shales for unconventional gas in Northern Europe and currently is of great interest to hydrocarbon exploration and production. Due to low permeability of shales, economically viable production requires hydraulic fracturing of the reservoir. The design of hydrofractures requires an estimate of stress state within the reservoir and geomechanical properties such as Young's modulus and Poisson's ratio. Shales are often highly anisotropic and the models which neglect shale anisotropy may fail to predict the behaviour of hydrofractures. Seismic attenuation anisotropy, on the other hand, can play a key role in quantitative rock characterization. Where the attenuation anisotropy can potentially be linked to anisotropic permeability of shales, its fluid/gas saturation and preferred development of anisotropic fracture orientations. In this research, by utilizing the so-called Thomsen's notations, the elastic anisotropy of our (fractured and unfractured) shales has been investigated using a pulse transmission technique in the ultrasonic frequency range (0.3-1 MHz). Assuming transverse isotropy of the shales, and taking the axis x3 as the axis of rotational symmetry, directional Young's moduli and Poisson's ratios were obtained. The Young's modulus measured parallel to bedding (E1) is found to be larger than the Young's modulus measured orthogonal to bedding (E3). In case of the Poisson's ratios, we found that ν31 is larger than ν12, where νijrelates elastic strain in xj direction to stress applied in xi direction. Finally, attenuation anisotropy in dry and layer-parallel fractured Posidonia shale samples has been studied in the same frequency range. The attenuation of compressional (QP-1) and shear (QS-1) waves increases substantially with a macro (or wavelength) fracture introduction, especially for P and S waves propagating orthogonal to the bedding. In non-fractured and fractured dry shales, QP-1 is

  7. Time-dependent deformation of gas shales - role of rock framework versus reservoir fluids

    NASA Astrophysics Data System (ADS)

    Hol, Sander; Zoback, Mark

    2013-04-01

    Hydraulic fracturing operations are generally performed to achieve a fast, drastic increase of permeability and production rates. Although modeling of the underlying short-term mechanical response has proven successful via conventional geomechanical approaches, predicting long-term behavior is still challenging as the formation interacts physically and chemically with the fluids present in-situ. Recent experimental work has shown that shale samples subjected to a change in effective stress deform in a time-dependent manner ("creep"). Although the magnitude and nature of this behavior is strongly related to the composition and texture of the sample, also the choice of fluid used in the experiments affects the total strain response - strongly adsorbing fluids result in more, recoverable creep. The processes underlying time-dependent deformation of shales under in-situ stresses, and the long-term impact on reservoir performance, are at present poorly understood. In this contribution, we report triaxial mechanical tests, and theoretical/thermodynamic modeling work with the aim to identify and describe the main mechanisms that control time-dependent deformation of gas shales. In particular, we focus on the role of the shale solid framework versus the type and pressure of the present pore fluid. Our experiments were mainly performed on Eagle Ford Shale samples. The samples were subjected to cycles of loading and unloading, first in the dry state, and then again after equilibrating them with (adsorbing) CO2 and (non-adsorbing) He at fluid pressures of 4 MPa. Stresses were chosen close to those persisting under in-situ conditions. The results of our tests demonstrate that likely two main types of deformation mechanisms operate that relate to a) the presence of microfractures as a dominating feature in the solid framework of the shale, and b) the adsorbing potential of fluids present in the nanoscale voids of the shale. To explain the role of adsorption in the observed

  8. Shale Oil Value Enhancement Research

    SciTech Connect

    James W. Bunger

    2006-11-30

    Raw kerogen oil is rich in heteroatom-containing compounds. Heteroatoms, N, S & O, are undesirable as components of a refinery feedstock, but are the basis for product value in agrochemicals, pharmaceuticals, surfactants, solvents, polymers, and a host of industrial materials. An economically viable, technologically feasible process scheme was developed in this research that promises to enhance the economics of oil shale development, both in the US and elsewhere in the world, in particular Estonia. Products will compete in existing markets for products now manufactured by costly synthesis routes. A premium petroleum refinery feedstock is also produced. The technology is now ready for pilot plant engineering studies and is likely to play an important role in developing a US oil shale industry.

  9. Exxon's abrupt exit from shale

    SciTech Connect

    Tracy, E.J.

    1982-05-31

    Exxon blames its sudden turnaround from a 1980 decision to develop 47,000 barrels of shale oil a day in western Colorado on high construction costs. The company's Colony project investment has already been $920 million, but final cost estimates are now double earlier predictions. A major setback to the synfuels industry, the cancellation leaves only two small commercial projects, one for coal gasification and the other an adjacent shale-oil project. It is also a victory for Saudi Arabia's strategy of keeping OPEC prices competitive. Analysts suggest that Exxon's decision is related to association with Tosco Corp., a 23% drop in profits during the first quarter, and a reduced cash flow. Exxon denies that these explanations or the current petroleum glut were pertinent. (DCK)

  10. Review of Emerging Resources: U.S. Shale Gas and Shale Oil Plays

    EIA Publications

    2011-01-01

    To gain a better understanding of the potential U.S. domestic shale gas and shale oil resources, the Energy Information Administration (EIA) commissioned INTEK, Inc. to develop an assessment of onshore lower 48 states technically recoverable shale gas and shale oil resources. This paper briefly describes the scope, methodology, and key results of the report and discusses the key assumptions that underlie the results.

  11. International developments in oil shale

    SciTech Connect

    Uthus, D.B.

    1985-08-01

    An overview of oil shale research and development outside the US provides a status report on technology approaches under active consideration in Australia, Brazil, Canada, China, West Germany, Israel, Jordan, Morocco, Soviet Union, Thailand, Turkey, and Yugoslavia. The status report covers the development plans and project costs of industrial projects. The technologies under consideration include the Fushun, Galoter, Kiviter, Lurgi, and Petrosix processes. 10 references.

  12. Developments in oil shale in 1987

    SciTech Connect

    Knutson, C.F.; Dana, G.F.; Solti, G.; Qian, J.L.; Ball, F.D.; Hutton, A.C.; Hanna, J.; Russell, P.L.; Piper, E.M.

    1988-10-01

    Oil shale development continued at a slow pace in 1987. The continuing interest in this commodity is demonstrated by the 342 oil shale citations added to the US Department of Energy Energy Database during 1987. The Unocal project in Parachute, Colorado, produced 600,000 bbl of synfuel in 1987. An appreciable amount of 1987's activity was associated with the nonsynfuel uses of oil shale. 4 figs., 2 tabs.

  13. Introduction to special section: China shale gas and shale oil plays

    USGS Publications Warehouse

    Jiang, Shu; Zeng, Hongliu; Zhang, Jinchuan; Fishman, Neil; Bai, Baojun; Xiao, Xianming; Zhang, Tongwei; Ellis, Geoffrey S.; Li, Xinjing; Richards-McClung, Bryony; Cai, Dongsheng; Ma, Yongsheng

    2015-01-01

    Even though China shale gas and shale oil exploration is still in an early stage, limited data are already available. We are pleased to have selected eight high-quality papers from fifteen submitted manuscripts for this timely section on the topic of China shale gas and shale oil plays. These selected papers discuss various subject areas including regional geology, resource potentials, integrated and multidisciplinary characterization of China shale reservoirs (geology, geophysics, geochemistry, and petrophysics) China shale property measurement using new techniques, case studies for marine, lacustrine, and transitional shale deposits in China, and hydraulic fracturing. One paper summarizes the regional geology and different tectonic and depositional settings of the major prospective shale oil and gas plays in China. Four papers concentrate on the geology, geochemistry, reservoir characterization, lithologic heterogeneity, and sweet spot identification in the Silurian Longmaxi marine shale in the Sichuan Basin in southwest China, which is currently the primary focus of shale gas exploration in China. One paper discusses the Ordovician Salgan Shale in the Tarim Basin in northwest China, and two papers focus on the reservoir characterization and hydraulic fracturing of Triassic lacustrine shale in the Ordos Basin in northern China. Each paper discusses a specific area.

  14. Eastern Devonian shales: Organic geochemical studies

    SciTech Connect

    Berger, I.A.; Hatchner, P.G.; Miknis, F.P.; Romankiw, L.A.

    1983-02-01

    The Eastern Devonian shales are represented by a sequence of sediments extending from New York state, south to the northern regions of Georgia and Alabama, and west into Ohio and to the Michigan and Illinois Basins. Correlatives are known in Texas. The shale is regionally known by a number of names: Chattanooga, Dunkirk, Rhinestreet, Huron, Antrim, Ohio, Woodford, etc. These shales, other than those in Texas, have elicited much interest because they have been a source of unassociated natural gas. It is of particular interest, however, that most of these shales have no associated crude oil, in spite of the fact that they have some of the characteristics normally attributed to source beds. This paper addresses some of the organic geochemical aspects of the kerogen in these shales, in relation to their oil generating potential. Past organic geochemical studies on Eastern Devonian shales are reviewed. Recent solid state /sup 13/C NMR studies on the nature of the organic matter in Eastern Devonian shales show that Eastern Devonian shales contain a larger fraction of aromatic carbon in their chemical composition. Thus, despite their high organic matter contents, their potential as a petroleum source rock is low, because the kerogen in these shales is of a ''coaly'' nature and hence more prone to producing natural gas.

  15. Oil shale oxidation at subretorting temperatures

    SciTech Connect

    Jacobson, I.A. Jr.

    1980-06-01

    Green River oil shale was air oxidized at subretorting temperatures. Off gases consisting of nitrogen, oxygen, carbon monoxide, carbon dioxide, and water were monitored and quantitatively determined. A mathematical model of the oxidation reactions based on a shrinking core model has been developed. This model incorporates the chemical reaction of oxygen and the organic material in the oil shale as well as the diffusivity of the oxygen into the shale particle. Diffusivity appears to be rate limiting for the oxidation. Arrhenius type equations, which include a term for oil shale grade, have been derived for both the chemical reaction and the diffusivity.

  16. Stratigraphic controls on fracturing in black and grey shale-dominated sequences

    NASA Astrophysics Data System (ADS)

    Imber, Jonathan; Armstrong, Howard; Herringshaw, Liam; McCaffrey, Ken; Trabucho-Alexandre, João; Trevelyan, Jon

    2013-04-01

    that large fluid overpressures (? ? 1) generated during clay diagenesis and/or kerogen maturation within the highly stratified (i.e. mechanically isotropic) Mulgrave Shale Member contributed to the development of bedding-parallel veins within the Jet Rock and Bituminous Shale. More speculatively, the spacing of the bedding-parallel veins may be controlled by metre- and sub-metre scale variations in organic and/or clay content throughout the Mulgrave Shale Member, which in turn may reflect primary sedimentary discontinuities. The regular spacing of compositional variations and discontinuity surfaces is likely to be a consequence of allogenic forcing mechanisms. By contrast, the SiO2-rich, TOC- and clay-poor Cement Shales appear to be compositionally more homogeneous. The Cement Shales deformed under conditions of higher effective normal stress (? < 1), giving rise to shear fractures with classic Andersonian geometries. Our observations suggest that stratigraphy exerts a strong control on fracturing within thick, shale-dominated sequences. However, the relationship between "mechanical stratigraphy" and fracture spacing and orientation appears to be more complex than in conventional clastic reservoir sequences.

  17. Effect of retorting and oven cooking on the nutritional properties of beef frankfurters blended with palm oils.

    PubMed

    Wan Rosli, W I; Babji, A S; Aminah, A; Foo, S P; Abd Malik, O

    2010-08-01

    The effect of retorting and oven cooking on the nutritional properties of beef frankfurters blended with palm oil (PO), red PO35 and red PO48 were compared against the control beef fat treatment. Red PO oven-cooked beef frankfurters resulted in a significant loss of vitamin E from 538.5 to 287.5 microg after 6 months. Oven cooked sausages stored at -18 degrees C and retorted sausages stored for the 6 months of shelf studies resulted in more than 90% loss of alpha-carotene and beta-carotene in red PO beef frankfurters. Cholesterol was reduced at the range of 29.0-32.2 mg/100 g when beef fat was substituted with palm-based oils, in beef frankfurters. Differences of heat treatments did not significantly change THE cholesterol content, within all treatments. This study showed the potential of utilizing red palm oils as animal fat analogues in improving vitamin E, reducing cholesterol but not carotenes in beef frankfurters.

  18. Characterization of DOE reference oil shales: Mahogany Zone, Parachute Creek Member, Green River Formation Oil Shale, and Clegg Creek Member, New Albany Shale

    SciTech Connect

    Miknis, F. P.; Robertson, R. E.

    1987-09-01

    Measurements have been made on the chemical and physical properties of two oil shales designated as reference oil shales by the Department of Energy. One oil shale is a Green River Formation, Parachute Creek Member, Mahogany Zone Colorado oil shale from the Exxon Colony mine and the other is a Clegg Creek Member, New Albany shale from Kentucky. Material balance Fischer assays, carbon aromaticities, thermal properties, and bulk mineralogic properties have been determined for the oil shales. Kerogen concentrates were prepared from both shales. The measured properties of the reference shales are comparable to results obtained from previous studies on similar shales. The western reference shale has a low carbon aromaticity, high Fischer assay conversion to oil, and a dominant carbonate mineralogy. The eastern reference shale has a high carbon aromaticity, low Fischer assay conversion to oil, and a dominant silicate mineralogy. Chemical and physical properties, including ASTM distillations, have been determined for shale oils produced from the reference shales. The distillation data were used in conjunction with API correlations to calculate a large number of shale oil properties that are required for computer models such as ASPEN. There was poor agreement between measured and calculated molecular weights for the total shale oil produced from each shale. However, measured and calculated molecular weights agreed reasonably well for true boiling point distillate fractions in the temperature range of 204 to 399/sup 0/C (400 to 750/sup 0/F). Similarly, measured and calculated viscosities of the total shale oils were in disagreement, whereas good agreement was obtained on distillate fractions for a boiling range up to 315/sup 0/C (600/sup 0/F). Thermal and dielectric properties were determined for the shales and shale oils. The dielectric properties of the reference shales and shale oils decreased with increasing frequency of the applied frequency. 42 refs., 34 figs., 24

  19. Stress

    MedlinePlus

    ... hurt or killed. Examples include a major accident, war, assault, or a natural disaster. This type of ... stress, so you can avoid more serious health effects. NIH: National Institute of Mental Health

  20. Outcrop descriptions of the Antrim shale

    SciTech Connect

    Hathon, C.; Sibley, D.; Cambray, F.W.

    1980-04-01

    Samples of Michigan Basin Antrim shale were taken from each of the three locations where the shale is exposed at the surface in sufficient quantity to be studied. Detailed stratigraphic descriptions were prepared. Although there is considerable variation between individual beds, there are no unique units which can be used for lithological correlation.

  1. Metal flux in black shale sequences

    SciTech Connect

    Parnell, J. . School of Geosciences)

    1992-01-01

    Black shales are important to the models used by many metallogenists to explain the concentration of metals in and around ore prospects. In some cases, black shales are inferred to be a ready source of metals which can be leached and concentrated to form a mineral deposit. For others, black shales are a chemical trap in which organic matter absorbs metals from migrating groundwaters and hydrothermal fluids. Clearly, these source and sink models confer fundamentally opposite roles to black shales in the metal budget of a sedimentary base. An assessment of whether one of these roles is predominant must include consideration of the physico-chemical mechanism involved and their timing during basin history. A release of metals from shales can be a consequence of intrinsic diagenetic processes, in addition to scavenging by hydrothermal fluids (i.e. an external source). Major processes in siliciclastic diagenesis include compaction, silica precipitation/dissolution, clay authigenesis and carbonate/sulphate dissolution; the latter two in particular can be a source of metals due to expulsion from the lattice during mineral transformation. Both of these processes can occur on a large scale and liberate large quantities of metal over a short time period. One of several approaches to assessing the metal budget in/out of shales is to compare metal contents in shales outside and inside early diagenetic carbonate concretions which should protect their contents from the processes of deep burial. Results of such analyses suggest that black shales are more likely to absorb than lose metals.

  2. Indirect heating pyrolysis of oil shale

    DOEpatents

    Jones, Jr., John B.; Reeves, Adam A.

    1978-09-26

    Hot, non-oxygenous gas at carefully controlled quantities and at predetermined depths in a bed of lump oil shale provides pyrolysis of the contained kerogen of the oil shale, and cool non-oxygenous gas is passed up through the bed to conserve the heat

  3. Chemical kinetics and oil shale process design

    SciTech Connect

    Burnham, A.K.

    1993-07-01

    Oil shale processes are reviewed with the goal of showing how chemical kinetics influences the design and operation of different processes for different types of oil shale. Reaction kinetics are presented for organic pyrolysis, carbon combustion, carbonate decomposition, and sulfur and nitrogen reactions.

  4. Scales over Shale: How Pennsylvania Got Fracked

    NASA Astrophysics Data System (ADS)

    Sica, Carlo E.

    Shale gas has become one of Pennsylvania's major resources in recent years and the gas boom has proceeded in spite of uncertainty over the environmental risks of its production process. This thesis argues that location alone cannot explain why shale gas boomed in Pennsylvania. Using interviews with corporate and state executives, I argue that the scalar dimensions of the neoliberal environmental governance of shale gas were critical to understanding why shale gas boomed in Pennsylvania. These actors supported the preemption of local scales of governance by the state as a scalar fix for capital accumulation from shale gas development. They also legitimated the scalar fix by assembling a neat stack of scale frames that made shale gas seem to benefit everyone. These scale frames made shale gas appear as if it would provide local employment, regional supplies of cheap gas, national energy security, abundant gas for tight global markets, and a mitigating strategy for global climate change. In arguing this point, I present a history of how shale gas became a resource that outlines the critical role of the state in that process.

  5. Gas composition shifts in Devonian shales

    SciTech Connect

    Schettler, P.D.; Parmely, C.R. )

    1989-08-01

    Analysis of the gas composition of Devonian shale wells indicates that the composition of produced gas shifts during the production history of the well. Possible mechanisms to explain this behavior are examined in light of field and laboratory data. Application of diffusion theory is made to explain adsorption-like behavior exhibited by some shales.

  6. Cleanouts boost Devonian shale gas flow

    SciTech Connect

    Not Available

    1991-02-04

    Cleaning shale debris from the well bores is an effective way to boost flow rates from old open hole Devonian shale gas wells, research on six West Virginia wells begun in 1985 has shown. Officials involved with the study say the Appalachian basin could see 20 year recoverable gas reserves hiked by 315 bcf if the process is used on a wide scale.

  7. Effect of pasteurization, high-pressure processing, and retorting on the barrier properties of nylon 6, nylon 6/ethylene vinyl alcohol, and nylon 6/nanocomposites films.

    PubMed

    Halim, L; Pascall, M A; Lee, J; Finnigan, B

    2009-01-01

    This study determined the impact of pasteurization, high-pressure processing (HPP), and retorting on the barrier properties of nylon 6 (N6), nylon 6/ethylene vinyl alcohol (N6/EVOH), and nylon 6/nanocomposite (N6/nano) materials. The pasteurized and high-pressure treated films were coextruded with low-density polyethylene (PE) as the heat-sealing layer. The retorted films were coextruded with polypropylene (PP). Oxygen transmission rate (OTR) and water vapor transmission rate (WVTR) of the samples were measured after pasteurization (75 degrees C for 30 min), HPP (800 MPa for 10 min at 70 degrees C), and retorting (121 degrees C for 30 min) treatments. These were compared with the thermal characteristics and morphologies of the samples using differential scanning calorimetry (DSC) and X-ray diffraction (XRD). Results showed that OTR of N6 and N6/Nano increased after HPP (16.9% and 39.7%), pasteurization (13.3% and 75.9%), and retorting (63.3% and 112.6%), respectively. For N6/EVOH, a decrease in OTR after HPP (53.9%) and pasteurization (44.5%) was observed. The HPP treatment increased the WVTR of N6 (21.0%), N6/EVOH (48.9%), and N6/Nano (21.2%). The WVTR of N6, N6/EVOH, and N6/Nano increased by 96.7%, 43.8%, and 40.7%, respectively, after pasteurization. The DSC analyses showed that the enthalpy and percent crystallinity increased (2.3% to 6.5%) in the N6/Nano when compared with the N6 material after each treatment. Retorting caused a decrease (3.5%) in the percent crystallinity of the polypropylene material. HPP did not cause major morphological changes to the samples. Results of the barrier studies were influenced by the crystallinity changes in the materials as seen in the XRD diffractograms.

  8. The Shale Gas in Europe project (GASH)

    NASA Astrophysics Data System (ADS)

    Schulz, Hans-Martin; Horsfield, Brian; Gash-Team

    2010-05-01

    At the present time no shale gas play has been brought to the production level in Europe. While the opportunities appear abundant, there are still many challenges to be overcome in Europe such as land access and environmental issues. Costs per well are still higher than in the US, and mining regulations are tighter. As yet it remains unclear whether European shales can support commercial shale gas production. First, it will be essential to test the sub-surface and the potential deliverability of wells, supported by basic research. GASH is the first major scientific initiative in Europe that is focussed on shale gas; it is ambitious in that it is broad ranging in scientific scope and that it unites leading European research groups and geological surveys with industry. US know-how is also integrated into the programme to avoid reinventing the wheel, or, still worse, the flat tyre. GASH is currently funded by eight companies, and comprises two main elements: compilation of a European Black Shale Database (EBSD) and focussed research projects that are based on geochemical, geophysical and geomechanical investigations. The EBSD is being built by a team of more than 20 geological surveys, extending from Sweden in the north, through western Europe and the Baltic states down to southern Europe, and over to Romania, Hungary and the Czech Republic in the east. The research projects apply numerical modelling, process simulations and laboratory analyses to selected regional study areas or "natural laboratories" from both Europe and the USA - the goal: to predict gas-in-place and fracability based on process understanding. The European black shales selected as natural shale gas laboratories are the Cambrian Alum Shale from Sweden and Denmark, the Lower Jurassic Posidonia Shale from Central Germany, and Carboniferous black shales from the UK in the west via the Netherlands to Germany in the east. Fresh core material for detailed investigations will be recovered during the mid

  9. Thermomechanical properties of selected shales

    SciTech Connect

    Hansen, F.D.; Vogt, T.J.

    1987-08-01

    The experimental work discussed in this report is part of an ongoing program concerning evaluation of sedimentary and other rock types as potential hosts for a geologic repository. The objectives are the development of tools and techniques for repository characterization and performance assessment in a diversity of geohydrologic settings. This phase of the program is a laboratory study that investigates fundamental thermomechanical properties of several different shales. Laboratory experiments are intrinsically related to numerical modeling and in situ field experiments, which together will be used for performance assessment.

  10. Origin of the quartz in Antrim Shale

    SciTech Connect

    Hathon, C.; Sibley, D.; Cambray, F.W.

    1980-02-15

    Study of the macroscopic and microscopic properties of the Antrim Shale indicated an important anomaly, the quartz. The Antrim Shale (Devonian, Michigan Basin) contains a large, but quantitatively undertermineable volume of authigenic quartz. The shale contains approximately 50% quartz by weight of which, in the >500 mesh size fraction, 56% is polycrystalline. This is approximately 2X the amount of quartz in most shales and 10X the amount of polycrystalline quartz in the silt-size fraction of sandstones and shales. Scanning electron microscopy reveals an authigenic surface composed of hexagonal tabular plates which coalesce to form smooth grain surfaces. These plates have not been previously reported on quartz grains. Oxygen isotopes of quartz and carbonate phases are interpreted to indicate a gradual isotopic lightening of the pore fluids, from approximately -4/sup 0///sub 00/. Most of the authigenic quartz has a delta/sup 18/O = 22/sup 0///sub 00/ (SMOW).

  11. A model for hydrostatic consolidation of Pierre shale

    USGS Publications Warehouse

    Savage, W.Z.; Braddock, W.A.

    1991-01-01

    This paper presents closed-form solutions for consolidation of transversely isotropic porous media under hydrostatic stress. The solutions are applied to model the time variation of pore pressure, volume strain and strains parallel and normal to bedding, and to obtain coefficients of consolidation and permeability, as well as other properties, and the bulk modulus resulting from hydrostatic consolidation of Pierre shale. It is found that the coefficients consolidation and permeability decrease and the bulk moduli increase with increasing confining pressure, reflecting the closure of voids in the rock. ?? 1991.

  12. The Multi-Porosity Multi-Permeability and Electrokinetic Natures of Shales and Their Effects in Hydraulic Fracturing of Unconventional Shale Reservoirs

    NASA Astrophysics Data System (ADS)

    Liu, C.; Hoang, S. K.; Tran, M. H.; Abousleiman, Y. N.

    2013-12-01

    Imaging studies of unconventional shale reservoir rocks have recently revealed the multi-porosity multi-permeability nature of these intricate formations. In particular, the porosity spectrum of shale reservoir rocks often comprises of the nano-porosity in the organic matters, the inter-particle micro-porosity, and the macroscopic porosity of the natural fracture network. Shale is also well-known for its chemically active behaviors, especially shrinking and swelling when exposed to aqueous solutions, as the results of pore fluid exchange with external environment due to the difference in electro-chemical potentials. In this work, the effects of natural fractures and electrokinetic nature of shale on the formation responses during hydraulic fracturing are examined using the dual-poro-chemo-electro-elasticity approach which is a generalization of the classical Biot's poroelastic formulation. The analyses show that the presence of natural fractures can substantially increase the leak-off rate of fracturing fluid into the formation and create a larger region of high pore pressure near the fracture face as shown in Fig.1a. Due to the additional fluid invasion, the naturally fractured shale swells up more and the fracture aperture closes faster compared to an intrinsically low permeability non-fractured shale formation as shown in Fig.1b. Since naturally fractured zones are commonly targeted as pay zones, it is important to account for the faster fracture closing rate in fractured shales in hydraulic fracturing design. Our results also show that the presence of negative fixed charges on the surface of clay minerals creates an osmotic pressure at the interface of the shale and the external fluid as shown in Fig.1c. This additional Donnan-induced pore pressure can result in significant tensile effective stresses and tensile damage in the shale as shown in Fig.1d. The induced tensile damage can exacerbate the problem of proppant embedment resulting in more fracture closure

  13. View on oil shale development

    SciTech Connect

    Weichman, B.

    1984-04-01

    An examination of energy statistics shows clearly that the US is on the edge of an impending energy crisis. This appears preposterous in the face of a world oil glut and probable world oil price decreases over the next year or so. However, oil supply, oil demand and US economy statistics support the scenario of a rapidly occurring energy crisis in the US should oil imports be shut off even partially. This is not an unlikely happening under present world tensions. Oil and gas exploration and production statistics support the view that domestic oil reserves will continue to decline even if concentrated oil exploration activity were maintained. The shortest avenue for US energy independence is through the development of synthetic fuels. However, a detailed study shows that, under present technology, synthetic fuels cannot be produced economically regardless of the price of crude oil. One exception to this economic situation is shale oil coproduced with other minerals from the vast Saline Zone oil shale resource of northwest Colorado.

  14. Advances in hydraulic fracturing technology in the antrim shale. Topical report, July 1994-December 1996

    SciTech Connect

    Frantz, J.H.; Hopkins, C.W.

    1996-12-01

    The primary objectives of this study were to evaluate hydraulic fracture geometry in the naturally-fractured Antrim Shale. As part of this research, stress profiling and numerous hydraulic fracture experiments were performed. The research project performed field-based studies to better understand hyraulic fracture growth in the Antrim. This understanding will make it possible to verify the optimal stimulation treatment for operators to use during the next five years. The research results succeeded in determining how hydraulic fractures grow in the Antrim Shale formation.

  15. 43 CFR 3905.10 - Oil shale lease exchanges.

    Code of Federal Regulations, 2011 CFR

    2011-10-01

    ... 43 Public Lands: Interior 2 2011-10-01 2011-10-01 false Oil shale lease exchanges. 3905.10 Section... MANAGEMENT, DEPARTMENT OF THE INTERIOR RANGE MANAGEMENT (4000) OIL SHALE MANAGEMENT-GENERAL Lease Exchanges § 3905.10 Oil shale lease exchanges. To facilitate the recovery of oil shale, the BLM may consider...

  16. 43 CFR 3905.10 - Oil shale lease exchanges.

    Code of Federal Regulations, 2013 CFR

    2013-10-01

    ... 43 Public Lands: Interior 2 2013-10-01 2013-10-01 false Oil shale lease exchanges. 3905.10 Section... MANAGEMENT, DEPARTMENT OF THE INTERIOR MINERALS MANAGEMENT (3000) OIL SHALE MANAGEMENT-GENERAL Lease Exchanges § 3905.10 Oil shale lease exchanges. To facilitate the recovery of oil shale, the BLM may...

  17. 43 CFR 3905.10 - Oil shale lease exchanges.

    Code of Federal Regulations, 2014 CFR

    2014-10-01

    ... 43 Public Lands: Interior 2 2014-10-01 2014-10-01 false Oil shale lease exchanges. 3905.10 Section... MANAGEMENT, DEPARTMENT OF THE INTERIOR MINERALS MANAGEMENT (3000) OIL SHALE MANAGEMENT-GENERAL Lease Exchanges § 3905.10 Oil shale lease exchanges. To facilitate the recovery of oil shale, the BLM may...

  18. Microstructure and rheology of limestone-shale fault rocks

    NASA Astrophysics Data System (ADS)

    Wells, R. K.; Newman, J.; Wojtal, S. F.

    2010-12-01

    The Copper Creek (CC) thrust fault in the southern Appalachians places Cambrian over Middle Ordovician sedimentary strata; restored cross sections indicate these strata were originally separated by 15-20 km and deformation along the CC occurred at temperatures of 100-180 C. Along the hangingwall-footwall contact is a ~2 cm thick shear zone composed of calcite and shale. Microstructures in the shear zone suggest that calcite, not shale, controlled the rheology of the shear zone rocks. Plasticity-induced fracturing in calcite resulted in ultrafine-grained (<1.0 µm) fault rocks that deformed by grain boundary sliding accommodated primarily by diffusion creep, suggesting low flow stresses. We used optical and electron microscopy to investigate samples from a transect across the shear zone and into the shale and micrite of the footwall host rocks. 1 cm below the base of the shear zone, sedimentary lamination in shale is cut by minor faults, stylolites, and 10-50 µm thick veins oriented parallel and perpendicular to the fault and filled by calcite crystals 5-25 µm in diameter. Within the non-pervasively deformed shale, fault-parallel calcite veins cross-cut and displace fault-perpendicular veins. At vein intersections, calcite grain size is reduced to ~0.3 µm, and microstructures include inter- and intragranular fractures, four-grain junctions, and interpenetrating grain boundaries. Porosity rises to 6% from < 1% in coarse (25 µm grain size) areas of calcite veins. In coarse calcite grains, trails of voids follow twin boundaries, and voids occur at many twin-twin and twin-grain boundary intersections. At the shear zone/footwall contact, a 350 µm thick calcite band is composed of coarse- and ultrafine-grained layers. Ultrafine-grained (~0.34 µm) layers contain microstructures similar to those at vein intersections in the footwall, and display no lattice-preferred orientation (LPO) of grains. Grain boundary alignments across many calcite grains occur at a low angle

  19. Joints and decollement zones in Middle Devonian shales. Evidence for multiple deformation events in the central Appalachian Plateau

    SciTech Connect

    Evans, M.A. )

    1994-04-01

    Fractures in oriented Middle Devonian shale cores from the Appalachian Plateau province provide evidence for multiple deformation events associated with the Alleghanian orogeny, post-orogenic stress relaxation, and neotectonic ( ) stresses. The orientation, distribution, and mineral paragenesis of these fractures are used to establish the timing, regional extent, and stress orientation of each deformation event. During the Alleghanian orogeny, the Middle Devonian shale section was a regional decollement zone in the central Appalachian Plateau province. The decollement extends from the Appalachian Structural Front to northwestern Pennsylvania and east-central Ohio. It is defined by abundant joints, veins, and slick-ensided fractures localized within multiple zones of organic-rich brown and black shale. These zones are distributed over tens to hundreds of meters of the Middle Devonian shale section. The shale cores record a continuous counterclockwise rotation of the maximum compressive stress direction in the west-central Appalachians during the Alleghanian orogeny. Three stages are recognized. 68 refs., 10 figs., 3 tabs.

  20. A review of the organic geochemistry of shales

    SciTech Connect

    Ho, P.C.; Meyer, R.E.

    1987-06-01

    Shale formations have been suggested as a potential site for a high level nuclear waste repository. As a first step in the study of the possible interaction of nuclides with the organic components of the shales, literature on the identification of organic compounds from various shales of the continent of the United States has been reviewed. The Green River shale of the Cenozoic era is the most studied shale followed by the Pierre shale of the Mesozoic era and the Devonian black shale of the Paleozoic era. Organic compounds that have been identified from these shales are hydrocarbons, fatty acids, fatty alcohols, steranes, terpanes, carotenes, carbohydrates, amino acids, and porphyrins. However, these organic compounds constitute only a small fraction of the organics in shales and the majority of the organic compounds in shales are still unidentified.

  1. Shale gas exploration potential in the UK

    NASA Astrophysics Data System (ADS)

    Smith, N.

    2009-04-01

    Shale gas exploration is one of the main new ‘unconventional' hydrocarbon plays and production is now a major contribution to USA's indigenous supply. BGS has begun a study of hydrocarbon exploration and other data to assess the potential in the UK. Key shale characteristics have been identified in the USA, including gas window maturity and high total organic carbon (TOC) content. Existing gasfields and discoveries containing migrated gas in conventional reservoirs are the obvious starting points. These prove gas has been generated. Discovering the nearby source rocks, which charged them, involves analysing the gas compositions and their carbon isotope characteristics, as well as delving into past exploration and well completion reports. Also used are parameters more widely available which act as surrogates (e.g. radioactivity for TOC). The main targets are Namurian and Dinantian black shales in northern England, source rocks for the small East Midlands oilfields. Lesser targets occur in southern England near small gasfields and discoveries, probably in Lower Jurassic shales, and possibly Kimmeridge Clay (Upper Jurassic). Their advantage is that natural permeabilities are probably higher than the older formations. Early Palaeozoic shales between the Caledonian and Variscan fold belts may also retain some potential but, unlike the association with the Alum Shale source rock in the Baltic, no gasfields have been discovered. Can shale gas production occur where there are no conventional fields?

  2. Phanerozoic black shales and the Wilson Cycle

    NASA Astrophysics Data System (ADS)

    Trabucho-Alexandre, J.; Hay, W. W.; de Boer, P. L.

    2011-09-01

    The spatial and temporal distribution of black shales is related to the development of the environments in which they accumulate and to a propitious combination of environmental variables. Whereas much has been done in recent years to improve our understanding of the mechanisms behind the temporal distribution of black shales in the Phanerozoic, the interpretation of the palaeogeographical distribution of black shales is still dominated by an oversimplistic set of three uniformitarian depositional models that do not capture the complexity and dynamics of environments of black shale accumulation. These three models, the restricted circulation, the (open) ocean oxygen minimum and the continental shelf models, are in fact a uniformitarian simplification of the variety of depositional environments that arise and coexist throughout the course of a basin's Wilson Cycle, i.e. the dynamic sequence of events and stages that characterise the evolution of an ocean basin, from the opening continental rift to the closing orogeny. We examine the spatial distribution of black shales in the context of the Wilson Cycle using examples from the Phanerozoic. It is shown that the geographical distribution of black shales, their position in the basin infill sequence and their nature (e.g. type of organic matter, lithology) depend on basin evolution because the latter controls the development of sedimentary environments where black shales may be deposited.

  3. Short and long-term strength of shale rocks

    NASA Astrophysics Data System (ADS)

    Rybacki, Erik; Dresen, Georg

    2016-04-01

    Stimulation of oil and gas bearing shales commonly utilizes advanced hydraulic fracturing techniques to enhance the production rate. Successful hydrofrac campaigns depend on the geomechanical properties of the reservoir. For example, the short term strength and brittleness may control the hydraulic breakdown pressure and borehole stability. The long term creep properties may determine the closure rate of hydraulically induced fractures, for example by proppant embedment. We performed a series of mechanical tests on shales with different mineral content, porosity and maturity. Cylindrical samples of 1-5 cm in diameter and 2-10 cm in length were deformed at confining pressures of 0.1 - 400 MPa and temperatures of 25°-400°C in constant strain rate and constant stress mode in order to evaluate the influence of loading conditions and composition on their strength and ductility. Short-term constant strain rate tests show that, at fixed loading direction with respect to bedding orientation, the peak strength and Young's modulus vary with mineral content, humidity and porosity, but depend also on applied pressure, temperature and strain rate. The (porosity-corrected) variation of peak strength and Young's modulus with composition can be roughly estimated from the mechanical behavior of all components at given pressure-temperature conditions and their volumetric proportion. Samples deforming in the brittle-semibrittle regime may be characterized by empirical brittleness indices based on their deformation behavior, Young's modulus, or bulk composition. These indices are correlated at low pressure-temperature conditions (corresponding to < about 4 km depth). First long-term deformation experiments at constant load show transient viscoplastic creep behavior. The associated strain rates increase with increasing differential stress, increasing temperature and decreasing pressure, accompanied by slight porosity reduction. Therefore, estimates of fracture healing rates by

  4. Kerogen extraction from subterranean oil shale resources

    DOEpatents

    Looney, Mark Dean; Lestz, Robert Steven; Hollis, Kirk; Taylor, Craig; Kinkead, Scott; Wigand, Marcus

    2010-09-07

    The present invention is directed to methods for extracting a kerogen-based product from subsurface (oil) shale formations, wherein such methods rely on fracturing and/or rubblizing portions of said formations so as to enhance their fluid permeability, and wherein such methods further rely on chemically modifying the shale-bound kerogen so as to render it mobile. The present invention is also directed at systems for implementing at least some of the foregoing methods. Additionally, the present invention is also directed to methods of fracturing and/or rubblizing subsurface shale formations and to methods of chemically modifying kerogen in situ so as to render it mobile.

  5. Kerogen extraction from subterranean oil shale resources

    DOEpatents

    Looney, Mark Dean; Lestz, Robert Steven; Hollis, Kirk; Taylor, Craig; Kinkead, Scott; Wigand, Marcus

    2009-03-10

    The present invention is directed to methods for extracting a kerogen-based product from subsurface (oil) shale formations, wherein such methods rely on fracturing and/or rubblizing portions of said formations so as to enhance their fluid permeability, and wherein such methods further rely on chemically modifying the shale-bound kerogen so as to render it mobile. The present invention is also directed at systems for implementing at least some of the foregoing methods. Additionally, the present invention is also directed to methods of fracturing and/or rubblizing subsurface shale formations and to methods of chemically modifying kerogen in situ so as to render it mobile.

  6. Experimental Determination of the Fracture Toughness and Brittleness of the Mancos Shale, Utah.

    NASA Astrophysics Data System (ADS)

    Chandler, Mike; Meredith, Phil; Crawford, Brian

    2013-04-01

    The hydraulic fracturing of Gas-Shales has become a topic of interest since the US Shale Gas Revolution, and is increasingly being investigated across Europe. A significant issue during hydraulic fracturing is the risk of fractures propagating further than desired into aquifers or faults. This occured at Preese Hall, UK in April and May 2011 when hydraulic fractures propagated into an adjacent fault causing 2.3ML and 1.7ML earthquakes [1]. A rigorous understanding of how hydraulic fractures propagate under in-situ conditions is therefore important for treatment design, both to maximise gas accessed, and to minimise risks due to fracture overextension. Fractures will always propagate along the path of least resistance, but the direction and extent of this path is a complex relationship between the in-situ stress-field, the anisotropic mechanical properties of the rock, and the pore and fracturing pressures [2]. It is possible to estimate the anisotropic in-situ stress field using an isolated-section hydraulic fracture test, and the pore-pressure using well logs. However, the anisotropic mechanical properties of gas-shales remain poorly constrained, with a wide range of reported values. In particular, there is an extreme paucity of published data on the Fracture Toughness of soft sediments such as shales. Mode-I Fracture Toughness is a measure of a material's resistance to dynamic tensile fracture propagation. Defects such as pre-existing microcracks and pores in a material can induce high local stress concentrations, causing fracture propagation and material failure under substantially lower stress than its bulk strength. The mode-I stress intensity factor, KI, quantifies the concentration of stress at the crack tip. For linear elastic materials the Fracture Toughness is defined by the critical value of this stress intensity factor; KIc, beyond which rapid catastrophic crack growth occurs. However, rocks such as shales are relatively ductile and display significant

  7. Geological setting of oil shales in the Permian phosphoria formation and some of the geochemistry of these rocks

    USGS Publications Warehouse

    Maughan, E.K.

    1983-01-01

    Recent studies of the Meade Peak and the Retort Phosphatic Shale Members of the Phosphoria Formation have investigated the organic carbon content and some aspects of hydrocarbon generation from these rocks. Phosphorite has been mined from the Retort and Meade Peak members in southeastern Idaho, northern Utah, western Wyoming and southwestern Montana. Organic carbon-rich mudstone beds associated with the phosphorite in these two members also were natural sources of petroleum. These mudstone beds were differentially buried throughout the region so that heating of these rocks has been different from place to place. Most of the Phosphoria source beds have been deeply buried and naturally heated to catagenetically form hydrocarbons. Deepest burial was in eastern Idaho and throughout most of the northeastern Great Basin where high ambient temperatures have driven the catagenesis to its limit and beyond to degrade or to destroy the hydrocarbons. In southwest Montana, however, burial in some areas has been less than 2 km, ambient temperatures remained low and the kerogen has not produced hydrocarbons (2). In these areas in Montana, the kerogen in the carbonaceous mudstone has retained the potential for hydrocarbon generation and the carbon-rich Retort Member is an oil shale from which hydrocarbons can be synthetically extracted. The Phosphoria Formation was deposited in a foreland basin between the Cordilleran geosyncline and the North American craton. This foreland basin, which coincides with the area of deposition of the two organic carbon-rich mudstone members of the Phosphoria, has been named the Sublett basin (Maughan, 1979). The basin has a northwest-southeast trending axis and seems to have been deepest in central Idaho where deep-water sedimentary rocks equivalent to the Phosphoria Formation are exceptionally thick. The depth of the basin was increasingly shallower away from central Idaho toward the Milk River uplift - a land area in Montana, the ancestral Rocky

  8. Paleontology: a new Burgess Shale fauna.

    PubMed

    Briggs, Derek E G

    2014-05-19

    A spectacular Cambrian soft bodied fauna some 40 km from Walcott's original Burgess Shale locality includes over 50 taxa, some 20% new to science. New anatomical evidence from this site will illuminate the evolution of early marine animals.

  9. Military jet fuel from shale oil

    NASA Technical Reports Server (NTRS)

    Coppola, E. N.

    1980-01-01

    Investigations leading to a specification for aviation turbine fuel produced from whole crude shale oil are described. Refining methods involving hydrocracking, hydrotreating, and extraction processes are briefly examined and their production capabilities are assessed.

  10. Ordovician faunas of Burgess Shale type.

    PubMed

    Van Roy, Peter; Orr, Patrick J; Botting, Joseph P; Muir, Lucy A; Vinther, Jakob; Lefebvre, Bertrand; el Hariri, Khadija; Briggs, Derek E G

    2010-05-13

    The renowned soft-bodied faunas of the Cambrian period, which include the Burgess Shale, disappear from the fossil record in the late Middle Cambrian, after which the Palaeozoic fauna dominates. The disappearance of faunas of Burgess Shale type curtails the stratigraphic record of a number of iconic Cambrian taxa. One possible explanation for this loss is a major extinction, but more probably it reflects the absence of preservation of similar soft-bodied faunas in later periods. Here we report the discovery of numerous diverse soft-bodied assemblages in the Lower and Upper Fezouata Formations (Lower Ordovician) of Morocco, which include a range of remarkable stem-group morphologies normally considered characteristic of the Cambrian. It is clear that biotas of Burgess Shale type persisted after the Cambrian and are preserved where suitable facies occur. The Fezouata biota provides a link between the Burgess Shale communities and the early stages of the Great Ordovician Biodiversification Event. PMID:20463737

  11. Ordovician faunas of Burgess Shale type.

    PubMed

    Van Roy, Peter; Orr, Patrick J; Botting, Joseph P; Muir, Lucy A; Vinther, Jakob; Lefebvre, Bertrand; el Hariri, Khadija; Briggs, Derek E G

    2010-05-13

    The renowned soft-bodied faunas of the Cambrian period, which include the Burgess Shale, disappear from the fossil record in the late Middle Cambrian, after which the Palaeozoic fauna dominates. The disappearance of faunas of Burgess Shale type curtails the stratigraphic record of a number of iconic Cambrian taxa. One possible explanation for this loss is a major extinction, but more probably it reflects the absence of preservation of similar soft-bodied faunas in later periods. Here we report the discovery of numerous diverse soft-bodied assemblages in the Lower and Upper Fezouata Formations (Lower Ordovician) of Morocco, which include a range of remarkable stem-group morphologies normally considered characteristic of the Cambrian. It is clear that biotas of Burgess Shale type persisted after the Cambrian and are preserved where suitable facies occur. The Fezouata biota provides a link between the Burgess Shale communities and the early stages of the Great Ordovician Biodiversification Event.

  12. Important geological properties of unconventional resource shales

    NASA Astrophysics Data System (ADS)

    Slatt, Roger M.

    2011-12-01

    The revelation of vast global quantities of potentially productive gas and oil-prone shales has led to advancements in understanding important geological properties which impact reservoir performance. Based upon research on a variety of shales, several geological properties have been recognized as being common and important to hydrocarbon production. (1) transport/depositional processes include hemipelagic `rain', hyperpycnal flows, turbidity current flows, tempestites, wave-reworking, and contour currents in both shallow and deep water settings. (2) Common shale minerals include clays, quartz, calcite, dolomite, apatite, and pyrite; organic constituents include spores ( Tasmanites), plant remains, biogenic quartz and calcite, and arenaceous foraminifera. (3) Porosity and permeability are characteristically low with pore sizes ranging down to the nanoscale. Main pore types include intergranular (including pores within clay floccules), porous organic matter, porous fecal pellets, and microfractures. (4) Important geochemical characteristics include organic richness (>3%), maturity (>1.1%Ro for shale gas and 0.6-0.9% for shale oil) and type (I-IV), in addition to certain biomarkers which are indicators of bottom water oxicity during deposition. Remaining hydrocarbon potential [RHP = (S1 + S2)/TOC] also reflects temporal environmental changes. `Isotopic reversals' can be used to detect best producing areas in shale-gas plays. (5) Lithofacies stacking patterns and sequence stratigraphy are the result of eustatic depositional history. A general sequence stratigraphic model is presented here that highlights this commonality. (6) Geomechanical properties are key to drilling, fracturing and production of hydrocarbons. Brittle-ductile couplets at several scales occur in shale sequences. (7) Geophysical properties, when calibrated to rock properties, provide a means of regionally to locally mapping the aforementioned properties. (8) Economic and societal considerations in

  13. Important geological properties of unconventional resource shales

    NASA Astrophysics Data System (ADS)

    Slatt, Roger

    2011-12-01

    The revelation of vast global quantities of potentially productive gas and oil-prone shales has led to advancements in understanding important geological properties which impact reservoir performance. Based upon research on a variety of shales, several geological properties have been recognized as being common and important to hydrocarbon production. (1) transport/depositional processes include hemipelagic `rain', hyperpycnal flows, turbidity current flows, tempestites, wave-reworking, and contour currents in both shallow and deep water settings. (2) Common shale minerals include clays, quartz, calcite, dolomite, apatite, and pyrite; organic constituents include spores (Tasmanites), plant remains, biogenic quartz and calcite, and arenaceous foraminifera. (3) Porosity and permeability are characteristically low with pore sizes ranging down to the nanoscale. Main pore types include intergranular (including pores within clay floccules), porous organic matter, porous fecal pellets, and microfractures. (4) Important geochemical characteristics include organic richness (>3%), maturity (>1.1%Ro for shale gas and 0.6-0.9% for shale oil) and type (I-IV), in addition to certain biomarkers which are indicators of bottom water oxicity during deposition. Remaining hydrocarbon potential [RHP = (S1 + S2)/TOC] also reflects temporal environmental changes. `Isotopic reversals' can be used to detect best producing areas in shale-gas plays. (5) Lithofacies stacking patterns and sequence stratigraphy are the result of eustatic depositional history. A general sequence stratigraphic model is presented here that highlights this commonality. (6) Geomechanical properties are key to drilling, fracturing and production of hydrocarbons. Brittle-ductile couplets at several scales occur in shale sequences. (7) Geophysical properties, when calibrated to rock properties, provide a means of regionally to locally mapping the aforementioned properties. (8) Economic and societal considerations in the

  14. Devonian shale gas resource assessment, Illinois basin

    SciTech Connect

    Cluff, R.M.; Cluff, S.G.; Murphy, C.M.

    1996-12-31

    In 1980 the National Petroleum Council published a resource appraisal for Devonian shales in the Appalachian, Michigan, and Illinois basins. Their Illinois basin estimate of 86 TCFG in-place has been widely cited but never verified nor revised. The NPC estimate was based on extremely limited canister off-gas data, used a highly simplified volumetric computation, and is not useful for targeting specific areas for gas exploration. In 1994 we collected, digitized, and normalized 187 representative gamma ray-bulk density logs through the New Albany across the entire basin. Formulas were derived from core analyses and methane adsorption isotherms to estimate total organic carbon (r{sup 2}=0.95) and gas content (r{sup 2}=0.79-0.91) from shale bulk density. Total gas in place was then calculated foot-by-foot through each well, assuming normal hydrostatic pressures and assuming the shale is gas saturated at reservoir conditions. The values thus determined are similar to peak gas contents determined by canister off-gassing of fresh cores but are substantially greater than average off-gas values. Greatest error in the methodology is at low reservoir pressures (or at shallow depths), however, the shale is generally thinner in these areas so the impact on the total resource estimate is small. The total New Albany gas in place was determined by integration to be 323 TCFG. Of this, 210 TCF (67%) is in the upper black Grassy Creek Shale, 72 TCF (23%) in the middle black and gray Selmier Shale, and 31 TCF (10%) in the basal black Blocher Shale. Water production concerns suggest that only the Grassy Creek Shale is likely to be commercially exploitable.

  15. Devonian shale gas resource assessment, Illinois basin

    SciTech Connect

    Cluff, R.M.; Cluff, S.G.; Murphy, C.M. )

    1996-01-01

    In 1980 the National Petroleum Council published a resource appraisal for Devonian shales in the Appalachian, Michigan, and Illinois basins. Their Illinois basin estimate of 86 TCFG in-place has been widely cited but never verified nor revised. The NPC estimate was based on extremely limited canister off-gas data, used a highly simplified volumetric computation, and is not useful for targeting specific areas for gas exploration. In 1994 we collected, digitized, and normalized 187 representative gamma ray-bulk density logs through the New Albany across the entire basin. Formulas were derived from core analyses and methane adsorption isotherms to estimate total organic carbon (r[sup 2]=0.95) and gas content (r[sup 2]=0.79-0.91) from shale bulk density. Total gas in place was then calculated foot-by-foot through each well, assuming normal hydrostatic pressures and assuming the shale is gas saturated at reservoir conditions. The values thus determined are similar to peak gas contents determined by canister off-gassing of fresh cores but are substantially greater than average off-gas values. Greatest error in the methodology is at low reservoir pressures (or at shallow depths), however, the shale is generally thinner in these areas so the impact on the total resource estimate is small. The total New Albany gas in place was determined by integration to be 323 TCFG. Of this, 210 TCF (67%) is in the upper black Grassy Creek Shale, 72 TCF (23%) in the middle black and gray Selmier Shale, and 31 TCF (10%) in the basal black Blocher Shale. Water production concerns suggest that only the Grassy Creek Shale is likely to be commercially exploitable.

  16. Processing needs and methodology for wastewaters from the conversion of coal, oil shale, and biomass to synfuels

    SciTech Connect

    Not Available

    1980-05-01

    The workshop identifies needs to be met by processing technology for wastewaters, and evaluates the suitability, approximate costs, and problems associated with current technology. Participation was confined to DOE Environmental Control Technology contractors to pull together and integrate past wastewater-related activities, to assess the status of synfuel wastewater treatability and process options, and to abet technology transfer. Particular attention was paid to probable or possible environmental restrictions which cannot be economically met by present technology. Primary emphasis was focussed upon process-condensate waters from coal-conversion and shale-retorting processes. Due to limited data base and time, the workshop did not deal with transients, upsets, trade-offs and system optimization, or with solids disposal. The report is divided into sections that, respectively, survey the water usage and effluent situation (II); identify the probable and possible water-treatment goals anticipated at the time when large-scale plants will be constructed (III); assess the capabilities, costs and shortcomings of present technology (IV); explore particularly severe environmental-control problems (V); give overall conclusions from the Workshop and recommendations for future research and study (VI); and, finally, present Status Reports of current work from participants in the Workshop (VII).

  17. Mechanism for Burgess Shale-type preservation.

    PubMed

    Gaines, Robert R; Hammarlund, Emma U; Hou, Xianguang; Qi, Changshi; Gabbott, Sarah E; Zhao, Yuanlong; Peng, Jin; Canfield, Donald E

    2012-04-01

    Exceptionally preserved fossil biotas of the Burgess Shale and a handful of other similar Cambrian deposits provide rare but critical insights into the early diversification of animals. The extraordinary preservation of labile tissues in these geographically widespread but temporally restricted soft-bodied fossil assemblages has remained enigmatic since Walcott's initial discovery in 1909. Here, we demonstrate the mechanism of Burgess Shale-type preservation using sedimentologic and geochemical data from the Chengjiang, Burgess Shale, and five other principal Burgess Shale-type deposits. Sulfur isotope evidence from sedimentary pyrites reveals that the exquisite fossilization of organic remains as carbonaceous compressions resulted from early inhibition of microbial activity in the sediments by means of oxidant deprivation. Low sulfate concentrations in the global ocean and low-oxygen bottom water conditions at the sites of deposition resulted in reduced oxidant availability. Subsequently, rapid entombment of fossils in fine-grained sediments and early sealing of sediments by pervasive carbonate cements at bed tops restricted oxidant flux into the sediments. A permeability barrier, provided by bed-capping cements that were emplaced at the seafloor, is a feature that is shared among Burgess Shale-type deposits, and resulted from the unusually high alkalinity of Cambrian oceans. Thus, Burgess Shale-type preservation of soft-bodied fossil assemblages worldwide was promoted by unique aspects of early Paleozoic seawater chemistry that strongly impacted sediment diagenesis, providing a fundamentally unique record of the immediate aftermath of the "Cambrian explosion." PMID:22392974

  18. Mechanism for Burgess Shale-type preservation

    PubMed Central

    Gaines, Robert R.; Hammarlund, Emma U.; Hou, Xianguang; Qi, Changshi; Gabbott, Sarah E.; Zhao, Yuanlong; Peng, Jin; Canfield, Donald E.

    2012-01-01

    Exceptionally preserved fossil biotas of the Burgess Shale and a handful of other similar Cambrian deposits provide rare but critical insights into the early diversification of animals. The extraordinary preservation of labile tissues in these geographically widespread but temporally restricted soft-bodied fossil assemblages has remained enigmatic since Walcott’s initial discovery in 1909. Here, we demonstrate the mechanism of Burgess Shale-type preservation using sedimentologic and geochemical data from the Chengjiang, Burgess Shale, and five other principal Burgess Shale-type deposits. Sulfur isotope evidence from sedimentary pyrites reveals that the exquisite fossilization of organic remains as carbonaceous compressions resulted from early inhibition of microbial activity in the sediments by means of oxidant deprivation. Low sulfate concentrations in the global ocean and low-oxygen bottom water conditions at the sites of deposition resulted in reduced oxidant availability. Subsequently, rapid entombment of fossils in fine-grained sediments and early sealing of sediments by pervasive carbonate cements at bed tops restricted oxidant flux into the sediments. A permeability barrier, provided by bed-capping cements that were emplaced at the seafloor, is a feature that is shared among Burgess Shale-type deposits, and resulted from the unusually high alkalinity of Cambrian oceans. Thus, Burgess Shale-type preservation of soft-bodied fossil assemblages worldwide was promoted by unique aspects of early Paleozoic seawater chemistry that strongly impacted sediment diagenesis, providing a fundamentally unique record of the immediate aftermath of the “Cambrian explosion.” PMID:22392974

  19. Mechanism for Burgess Shale-type preservation.

    PubMed

    Gaines, Robert R; Hammarlund, Emma U; Hou, Xianguang; Qi, Changshi; Gabbott, Sarah E; Zhao, Yuanlong; Peng, Jin; Canfield, Donald E

    2012-04-01

    Exceptionally preserved fossil biotas of the Burgess Shale and a handful of other similar Cambrian deposits provide rare but critical insights into the early diversification of animals. The extraordinary preservation of labile tissues in these geographically widespread but temporally restricted soft-bodied fossil assemblages has remained enigmatic since Walcott's initial discovery in 1909. Here, we demonstrate the mechanism of Burgess Shale-type preservation using sedimentologic and geochemical data from the Chengjiang, Burgess Shale, and five other principal Burgess Shale-type deposits. Sulfur isotope evidence from sedimentary pyrites reveals that the exquisite fossilization of organic remains as carbonaceous compressions resulted from early inhibition of microbial activity in the sediments by means of oxidant deprivation. Low sulfate concentrations in the global ocean and low-oxygen bottom water conditions at the sites of deposition resulted in reduced oxidant availability. Subsequently, rapid entombment of fossils in fine-grained sediments and early sealing of sediments by pervasive carbonate cements at bed tops restricted oxidant flux into the sediments. A permeability barrier, provided by bed-capping cements that were emplaced at the seafloor, is a feature that is shared among Burgess Shale-type deposits, and resulted from the unusually high alkalinity of Cambrian oceans. Thus, Burgess Shale-type preservation of soft-bodied fossil assemblages worldwide was promoted by unique aspects of early Paleozoic seawater chemistry that strongly impacted sediment diagenesis, providing a fundamentally unique record of the immediate aftermath of the "Cambrian explosion."

  20. Assessment of undiscovered shale gas and shale oil resources in the Mississippian Barnett Shale, Bend Arch–Fort Worth Basin Province, North-Central Texas

    USGS Publications Warehouse

    Marra, Kristen R.; Charpentier, Ronald R.; Schenk, Christopher J.; Lewan, Michael D.; Leathers-Miller, Heidi M.; Klett, Timothy R.; Gaswirth, Stephanie B.; Le, Phuong A.; Mercier, Tracey J.; Pitman, Janet K.; Tennyson, Marilyn E.

    2015-12-17

    Using a geology-based assessment methodology, the U.S. Geological Survey estimated mean volumes of 53 trillion cubic feet of shale gas, 172 million barrels of shale oil, and 176 million barrels of natural gas liquids in the Barnett Shale of the Bend Arch–Fort Worth Basin Province of Texas.

  1. Transport in shales and the design of improved water-based shale drilling fluids

    SciTech Connect

    Oort, E. van; Hale, A.H.; Mody, F.K.; Roy, S.

    1996-09-01

    Transport of water and ions in shales and its impact on shale stability were studied to facilitate the improvement of water-based muds as shale drilling fluids. Transport parameters associated with flows driven by gradients in pressure and chemical potential were quantified in key laboratory and full-scale experiments. The experimental results show that the low-permeability matrices of intact, clay-rich shales can act as imperfect or leaky membranes that will sustain osmotic flow of water. Moreover, the ability of shales to act as osmotic membranes is shown to provide a powerful new means for stabilizing these rocks when exposed to water-based drilling fluids. Guidelines are presented for effective exploitation of shale membrane action and induced osmotic flows through optimized water-based drilling fluid formulation. In addition, special attention is given to induced electro-osmotic water flow in shales driven by electric potential gradients, which may provide an exciting, new, environmentally benign means for stabilizing shale formations.

  2. Assessment of potential shale gas and shale oil resources of the Norte Basin, Uruguay, 2011

    USGS Publications Warehouse

    Schenk, Christopher J.; Kirschbaum, Mark A.; Charpentier, Ronald R.; Cook, Troy; Klett, Timothy R.; Gautier, Donald L.; Pollastro, Richard M.; Weaver, Jean N.; Brownfield, Michael

    2011-01-01

    Using a performance-based geological assessment methodology, the U.S. Geological Survey estimated mean volumes of 13.4 trillion cubic feet of potential technically recoverable shale gas and 0.5 billion barrels of technically recoverable shale oil resources in the Norte Basin of Uruguay.

  3. The Value of Water in Extraction of Natural Gas from the Marcellus Shale

    NASA Astrophysics Data System (ADS)

    Rimsaite, R.; Abdalla, C.; Collins, A.

    2013-12-01

    .60/1000 gallons in West Virginia and Pennsylvania, respectively. The additional water sales uniformly increased revenues and the financial status of water suppliers in some cases by substantial amounts. However, due to the temporary and uncertain demand for water from gas companies, many suppliers were cautious about reliance on these revenues. It must be stressed that the price charged reflects only a minimum value, or willingness to pay, by the shale gas companies for water. The full value of water for Marcellus shale gas production would include the costs of transportation, storage, and other activities to bring the water to the well drilling sites. Transportation costs are estimated in this research. The results are interpreted in light of other components of water value for shale gas production and compared to the estimated values of water in other industrial uses and in selected water consuming sectors.

  4. Microporoelastic Modeling of Organic-Rich Shales

    NASA Astrophysics Data System (ADS)

    Khosh Sokhan Monfared, S.; Abedi, S.; Ulm, F. J.

    2014-12-01

    Organic-rich shale is an extremely complex, naturally occurring geo-composite. The heterogeneous nature of organic-rich shale and its anisotropic behavior pose grand challenges for characterization, modeling and engineering design The intricacy of organic-rich shale, in the context of its mechanical and poromechanical properties, originates in the presence of organic/inorganic constituents and their interfaces as well as the occurrence of porosity and elastic anisotropy, at multiple length scales. To capture the contributing mechanisms, of 1st order, responsible for organic-rich shale complex behavior, we introduce an original approach for micromechanical modeling of organic-rich shales which accounts for the effect of maturity of organics on the overall elasticity through morphology considerations. This morphology contribution is captured by means of an effective media theory that bridges the gap between immature and mature systems through the choice of system's microtexture; namely a matrix-inclusion morphology (Mori-Tanaka) for immature systems and a polycrystal/granular morphology for mature systems. Also, we show that interfaces play a role on the effective elasticity of mature, organic-rich shales. The models are calibrated by means of ultrasonic pulse velocity measurements of elastic properties and validated by means of nanoindentation results. Sensitivity analyses using Spearman's Partial Rank Correlation Coefficient shows the importance of porosity and Total Organic Carbon (TOC) as key input parameters for accurate model predictions. These modeling developments pave the way to reach a "unique" set of clay properties and highlight the importance of depositional environment, burial and diagenetic processes on overall mechanical and poromechanical behavior of organic-rich shale. These developments also emphasize the importance of understanding and modeling clay elasticity and organic maturity on the overall rock behavior which is of critical importance for a

  5. Influence of Composition and Deformation Conditions on the Strength and Brittleness of Shale Rock

    NASA Astrophysics Data System (ADS)

    Rybacki, E.; Reinicke, A.; Meier, T.; Makasi, M.; Dresen, G. H.

    2015-12-01

    Stimulation of shale gas reservoirs by hydraulic fracturing operations aims to increase the production rate by increasing the rock surface connected to the borehole. Prospective shales are often believed to display high strength and brittleness to decrease the breakdown pressure required to (re-) initiate a fracture as well as slow healing of natural and hydraulically induced fractures to increase the lifetime of the fracture network. Laboratory deformation tests were performed on several, mainly European black shales with different mineralogical composition, porosity and maturity at ambient and elevated pressures and temperatures. Mechanical properties such as compressive strength and elastic moduli strongly depend on shale composition, porosity, water content, structural anisotropy, and on pressure (P) and temperature (T) conditions, but less on strain rate. We observed a transition from brittle to semibrittle deformation at high P-T conditions, in particular for high porosity shales. At given P-T conditions, the variation of compressive strength and Young's modulus with composition can be roughly estimated from the volumetric proportion of all components including organic matter and pores. We determined also brittleness index values based on pre-failure deformation behavior, Young's modulus and bulk composition. At low P-T conditions, where samples showed pronounced post-failure weakening, brittleness may be empirically estimated from bulk composition or Young's modulus. Similar to strength, at given P-T conditions, brittleness depends on the fraction of all components and not the amount of a specific component, e.g. clays, alone. Beside strength and brittleness, knowledge of the long term creep properties of shales is required to estimate in-situ stress anisotropy and the healing of (propped) hydraulic fractures.

  6. Shale Deformation Experiments Toward an Understanding of Elastic and Fracture Anisotropy

    NASA Astrophysics Data System (ADS)

    Kanitpanyacharoen, J.; Miyagi, L. M.; Jugle, M.; Wang, Y.; Yu, T.

    2014-12-01

    The significance of shales as unconventional hydrocarbon reservoirs has opened new research frontiers in geosciences. Among many of its unique physical properties, elastic anisotropy in shales has long been investigated by both experimental and computational approaches. Shales is highly anisotropic due to texture (crystallographic preferred orientation) of their constituent clay minerals. Moreover, texturing is known to cause fracture anisotropy, which can affect both fracture toughness and fracture orientations in metals, ceramics, and polyphase materials. However, the relationship between texture and fracture anisotropy in shale has not been explored. In this study we use the multi-anvil deformation tool (D-DIA) to deform shales with a range of clay and silt contents to failure while collecting x-ray diffraction and radiography images. Diffraction images are used to extract to texture and lattice strain evolution while radiography are used to measure macrostrain and determine failure. Since clay mineral have shear moduli in the range of 6-17 GPa, our stress resolution is in the range of 30 -100 MPa respectively, within the range of unconfined compressive strengths of shales. Our results show that the orientation of clay minerals become more prominent in all samples upon deforming the sample at 100 MPa. Recovered samples are investigated with SEM to document microstructural changes. A second deformation experiment will be coupled with ultrasonic and acoustic emissions measurements to make direct comparisons of elastic anisotropy and understand the role of fracture on anisotropy. Acoustic emissions allows us to locate damage initiation and determine fracture orientations in-situ. This information will be compared with texture data to determine fracture anisotropy in our samples.

  7. Double torsion fracture mechanics testing of shales under chemically reactive conditions

    NASA Astrophysics Data System (ADS)

    Chen, X.; Callahan, O. A.; Holder, J. T.; Olson, J. E.; Eichhubl, P.

    2015-12-01

    Fracture properties of shales is vital for applications such as shale and tight gas development, and seal performance of carbon storage reservoirs. We analyze the fracture behavior from samples of Marcellus, Woodford, and Mancos shales using double-torsion (DT) load relaxation fracture tests. The DT test allows the determination of mode-I fracture toughness (KIC), subcritical crack growth index (SCI), and the stress-intensity factor vs crack velocity (K-V) curves. Samples are tested at ambient air and aqueous conditions with variable ionic concentrations of NaCl and CaCl2, and temperatures up to 70 to determine the effects of chemical/environmental conditions on fracture. Under ambient air condition, KIC determined from DT tests is 1.51±0.32, 0.85±0.25, 1.08±0.17 MPam1/2 for Marcellus, Woodford, and Mancos shales, respectively. Tests under water showed considerable change of KIC compared to ambient condition, with 10.6% increase for Marcellus, 36.5% decrease for Woodford, and 6.7% decrease for Mancos shales. SCI under ambient air condition is between 56 and 80 for the shales tested. The presence of water results in a significant reduction of the SCI from 70% to 85% compared to air condition. Tests under chemically reactive solutions are currently being performed with temperature control. K-V curves under ambient air conditions are linear with stable SCI throughout the load-relaxation period. However, tests conducted under water result in an initial cracking period with SCI values comparable to ambient air tests, which then gradually transition into stable but significantly lower SCI values of 10-20. The non-linear K-V curves reveal that crack propagation in shales is initially limited by the transport of chemical agents due to their low permeability. Only after the initial cracking do interactions at the crack tip lead to cracking controlled by faster stress corrosion reactions. The decrease of SCI in water indicates higher crack propagation velocity due to

  8. Oil shales, evaporites and ore deposits

    NASA Astrophysics Data System (ADS)

    Eugster, Hans P.

    1985-03-01

    The relationships between oil shales, evaporites and sedimentary ore deposits can be classified in terms of stratigraphic and geochemical coherence. Oil shale and black shale deposition commonly follows continental red beds and is in turn followed by evaporite deposition. This transgressive-regressive sequence represents an orderly succession of depositional environments in space and time and results in stratigraphic coherence. The amount of organic carbon of a sediment depends on productivity and preservation, both of which are enhanced by saline environments. Work on Great Salt Lake. Utah, allows us to estimate that only 5% of TOC originally deposited is preserved. Inorganic carbonate production is similar to TOC production, but preservation is much higher. Oil shales and black shales commonly are enriched in heavy metals through scavenging by biogenic particles and complexation by organic matter. Ore deposits are formed from such rocks through secondary enrichment processes, establishing a geochemical coherence between oil shales and ore deposits. The Permian Kupferschiefer of N. Europe is used as an example to define a Kupferschiefer type (KST) deposit. Here oxygenated brines in contact with red beds become acidified through mineral precipitation and acquire metals by dissolving oxide coatings. Oxidation of the black shale leads to further acid production and metal acquisition and eventually to sulfide deposition along a reducing front. In order to form ore bodies, the stratigraphic coherence of the red bed-black shale-evaporite succession must be joined by the geochemical coherence of the ore body-evaporite-black shale association. The Cretaceous Cu-Zn deposits of Angola, the Zambian Copperbelt as well as the Creta, Oklahoma, deposits are other KST examples. In the Zambian Copperbelt, evaporites are indicated by the carbonate lenticles thought to be pseudomorphs after gypsum-anhydrite nodules. MVT deposits are also deposited by acid brines, but at more

  9. Proppant effects on maintaining fracture permeability in shale.

    NASA Astrophysics Data System (ADS)

    Ingraham, M. D.; Bauer, S. J.; Bolintineanu, D.; Rao, R. R.; Lechman, J. B.; Romero, J. A.

    2014-12-01

    A series of tests have been performed on manually fractured and propped shale. The shale used in this study contained 5-10% porosity, and 10-40% clay. Samples were fractured subparallel to bedding. Quartz sand (0.60-0.85 mm) was used as a proppant; proppant was manually placed on a fracture surface, resulting in a monolayer with random distribution. The specimens were repeatedly subjected to reservoir conditions, 20.7 MPa confining, 6.9 MPa differential stress, and temperature of 75 C. System permeability was measured during testing by flowing DI water through the specimen, flow rates were set to 0.002 ml/min, with the downstream vented to atmosphere. Upstream pressure varied to maintain the flow rate, and was approximately 1.4 MPa in the most recent (lowest permeability) test. Between test periods, specimens were removed from the test system and scanned with x-ray μCT. There is significant decrease in flow with subsequent testing due fracture closure. This is attributed to observations of clay swelling, proppant embedment, proppant fracture and shale wall sloughing. These lead to a decrease in effective fracture aperture. Flow induced particle transport clogs flow paths and impedes flow. Isolated grains tend to crush whereas continuous grains in proppant patches tend fracture with little displacement and tend towards embedment. Corresponding numerical simulations are underway to capture the change in crack flow due to these mechanisms. Images from the CT scans of the proppant filled crack are segmented and meshed. Then flow simulations are performed via the finite element method. Preliminary results are discussed. This work is a precursor to laboratory-scale shale fracture and proppant testing; cores will be hydraulically fractured and propped with appropriate proppant and fluid rheology. Proppant life and permeability reduction will be monitored and specimens will be scanned with μCT. Tests will be used to inform proppant flow models which seek to model

  10. Fracture-permeability behavior of shale

    SciTech Connect

    Carey, J. William; Lei, Zhou; Rougier, Esteban; Mori, Hiroko; Viswanathan, Hari

    2015-05-08

    The fracture-permeability behavior of Utica shale, an important play for shale gas and oil, was investigated using a triaxial coreflood device and X-ray tomography in combination with finite-discrete element modeling (FDEM). Fractures generated in both compression and in a direct-shear configuration allowed permeability to be measured across the faces of cylindrical core. Shale with bedding planes perpendicular to direct-shear loading developed complex fracture networks and peak permeability of 30 mD that fell to 5 mD under hydrostatic conditions. Shale with bedding planes parallel to shear loading developed simple fractures with peak permeability as high as 900 mD. In addition to the large anisotropy in fracture permeability, the amount of deformation required to initiate fractures was greater for perpendicular layering (about 1% versus 0.4%), and in both cases activation of existing fractures are more likely sources of permeability in shale gas plays or damaged caprock in CO₂ sequestration because of the significant deformation required to form new fracture networks. FDEM numerical simulations were able to replicate the main features of the fracturing processes while showing the importance of fluid penetration into fractures as well as layering in determining fracture patterns.

  11. Fracture-permeability behavior of shale

    DOE PAGES

    Carey, J. William; Lei, Zhou; Rougier, Esteban; Mori, Hiroko; Viswanathan, Hari

    2015-05-08

    The fracture-permeability behavior of Utica shale, an important play for shale gas and oil, was investigated using a triaxial coreflood device and X-ray tomography in combination with finite-discrete element modeling (FDEM). Fractures generated in both compression and in a direct-shear configuration allowed permeability to be measured across the faces of cylindrical core. Shale with bedding planes perpendicular to direct-shear loading developed complex fracture networks and peak permeability of 30 mD that fell to 5 mD under hydrostatic conditions. Shale with bedding planes parallel to shear loading developed simple fractures with peak permeability as high as 900 mD. In addition tomore » the large anisotropy in fracture permeability, the amount of deformation required to initiate fractures was greater for perpendicular layering (about 1% versus 0.4%), and in both cases activation of existing fractures are more likely sources of permeability in shale gas plays or damaged caprock in CO₂ sequestration because of the significant deformation required to form new fracture networks. FDEM numerical simulations were able to replicate the main features of the fracturing processes while showing the importance of fluid penetration into fractures as well as layering in determining fracture patterns.« less

  12. Mechanical and petrophysical study of fractured shale materials

    NASA Astrophysics Data System (ADS)

    Bonnelye, A.; Schubnel, A.; David, C.; Henry, P.; Guglielmi, Y.; Gout, C.; Dick, P.

    2015-12-01

    Mechanical and physical properties of shales are of major importance for upper crustal fault hydro-mechanical behavior. In particular, relationships between applied stress, textural anisotropy and transport properties. These relations can be investigated in the laboratory and here, was used shales from Tournemire (southern France). Triaxial tests were performed in order to determine the elasto-plastic yield envelope on 3 sets of samples with 3various bedding orientations (0°, 45°, and 90°). For each set, experiments were carried out at increasing confining pressures (2.5, 5, 10, 20, 40, 80MPa). They were performed under nominally drained conditions, at strain rates ranging between 5x10-7 s-1 - 1x10-5 s-1up to failure. During each experiment, P and S wave elastic velocities were continuously measured, in order to monitor the evolution of elastic anisotropy. Results show that the orientation of principal stress relative to bedding plays an important role on the brittle strength. Minimum strength is observed for samples deformed at 45° to bedding. Strength anisotropy increases both with confining pressure and strain rate. We interpret this result as the cohesive strength (and fracture toughness) being strain rate dependent. Although brittle failure and stress drops were systematically observed, deformation remained aseismic. This confirms that shales are good lithological candidates for shallow aseismic creep and slow slip events. Brittle failure was preceded by the development of P wave anisotropy, due to both crack growth and mineral re-orientation. Anisotropy variations were largest for samples deformed perpendicular to bedding, at the onset of rupture. Anisotropy reversal was observed at the highest confining pressures. For samples deformed parallel to bedding, the P wave anisotropy development is weaker. For both of these orientations, Thomsens parameters were inverted from the elastic wave data in order to quantify the evolution of elastic anisotropy. We

  13. Advanced retorting, microwave assisted thermal sterilization (MATS), and pressure assisted thermal sterilization (PATS) to process meat products.

    PubMed

    Barbosa-Cánovas, Gustavo V; Medina-Meza, Ilce; Candoğan, Kezban; Bermúdez-Aguirre, Daniela

    2014-11-01

    Conventional thermal processes have been very reliable in offering safe sterilized meat products, but some of those products are of questionable overall quality. Flavor, aroma, and texture, among other attributes, are significantly affected during such processes. To improve those quality attributes, alternative approaches to sterilizing meat and meat products have been explored in the last few years. Most of the new strategies for sterilizing meat products rely on using thermal approaches, but in a more efficient way than in conventional methods. Some of these emerging technologies have proven to be reliable and have been formally approved by regulatory agencies such as the FDA. Additional work needs to be done in order for these technologies to be fully adopted by the food industry and to optimize their use. Some of these emerging technologies for sterilizing meat include pressure assisted thermal sterilization (PATS), microwaves, and advanced retorting. This review deals with fundamental and applied aspects of these new and very promising approaches to sterilization of meat products.

  14. Methanogenic archaea in marcellus shale: a possible mechanism for enhanced gas recovery in unconventional shale resources.

    PubMed

    Tucker, Yael Tarlovsky; Kotcon, James; Mroz, Thomas

    2015-06-01

    Marcellus Shale occurs at depths of 1.5-2.5 km (5000 to 8000 feet) where most geologists generally assume that thermogenic processes are the only source of natural gas. However, methanogens in produced fluids and isotopic signatures of biogenic methane in this deep shale have recently been discovered. This study explores whether those methanogens are indigenous to the shale or are introduced during drilling and hydraulic fracturing. DNA was extracted from Marcellus Shale core samples, preinjected fluids, and produced fluids and was analyzed using Miseq sequencing of 16s rRNA genes. Methanogens present in shale cores were similar to methanogens in produced fluids. No methanogens were detected in injected fluids, suggesting that this is an unlikely source and that they may be native to the shale itself. Bench-top methane production tests of shale core and produced fluids suggest that these organisms are alive and active under simulated reservoir conditions. Growth conditions designed to simulate the hydrofracture processes indicated somewhat increased methane production; however, fluids alone produced relatively little methane. Together, these results suggest that some biogenic methane may be produced in these wells and that hydrofracture fluids currently used to stimulate gas recovery could stimulate methanogens and their rate of producing methane.

  15. New method for prediction of shale gas content in continental shale formation using well logs

    NASA Astrophysics Data System (ADS)

    Li, Sheng-Jie; Cui, Zhe; Jiang, Zhen-Xue; Shao, Yu; Liao, Wei; Li, Li

    2016-06-01

    Shale needs to contain a sufficient amount of gas to make it viable for exploitation. The continental heterogeneous shale formation in the Yan-chang (YC) area is investigated by firstly measuring the shale gas content in a laboratory and then investigating use of a theoretical prediction model. Key factors controlling the shale gas content are determined, and a prediction model for free gas content is established according to the equation of gas state and a new petrophysical volume model. Application of the Langmuir volume constant and pressure constant obtained from results of adsorption isotherms is found to be limited because these constants are greatly affected by experimental temperature and pressures. Therefore, using measurements of adsorption isotherms and thermodynamic theory, the influence of temperature, total organic carbon (TOC), and mineralogy on Langmuir volume constants and pressure constants are investigated in detail. A prediction model for the Langmuir pressure constant with a correction of temperatures is then established, and a prediction model for the Langmuir volume constant with correction of temperature, TOC, and quartz contents is also proposed. Using these corrected Langmuir constants, application of the Langmuir model determined using experimental adsorption isotherms is extrapolated to reservoir temperature, pressure, and lithological conditions, and a method for the prediction of shale gas content using well logs is established. Finally, this method is successfully applied to predict the shale gas content of the continental shale formation in the YC area, and practical application is shown to deliver good results with high precision.

  16. Methanogenic archaea in marcellus shale: a possible mechanism for enhanced gas recovery in unconventional shale resources.

    PubMed

    Tucker, Yael Tarlovsky; Kotcon, James; Mroz, Thomas

    2015-06-01

    Marcellus Shale occurs at depths of 1.5-2.5 km (5000 to 8000 feet) where most geologists generally assume that thermogenic processes are the only source of natural gas. However, methanogens in produced fluids and isotopic signatures of biogenic methane in this deep shale have recently been discovered. This study explores whether those methanogens are indigenous to the shale or are introduced during drilling and hydraulic fracturing. DNA was extracted from Marcellus Shale core samples, preinjected fluids, and produced fluids and was analyzed using Miseq sequencing of 16s rRNA genes. Methanogens present in shale cores were similar to methanogens in produced fluids. No methanogens were detected in injected fluids, suggesting that this is an unlikely source and that they may be native to the shale itself. Bench-top methane production tests of shale core and produced fluids suggest that these organisms are alive and active under simulated reservoir conditions. Growth conditions designed to simulate the hydrofracture processes indicated somewhat increased methane production; however, fluids alone produced relatively little methane. Together, these results suggest that some biogenic methane may be produced in these wells and that hydrofracture fluids currently used to stimulate gas recovery could stimulate methanogens and their rate of producing methane. PMID:25924080

  17. The Effects of Rock Mineralogy on Matrix Permeability in the Utica Shale

    NASA Astrophysics Data System (ADS)

    Al Ismail, M.; Zoback, M. D.

    2015-12-01

    We conducted pulse-decay permeability measurements on four horizontally oriented Utica Shale samples to examine the effects of rock mineralogy on transport mechanisms using both a non-adsorbing gas (Argon) and an adsorbing gas (CO2). The mineralogy of the shale samples varied from clay-rich to calcite-rich. We conducted the experiments at a temperature of 38.5°C, confining pressures ranging from 4.83 to 22.75 MPa, and pore fluid pressures ranging from 1.38 to 8.96 MPa. We measured the permeability at a range of confining pressures and pore pressures in order to independently test the effects of effective stress, confining pressure and pore pressure on permeability. Our results show that shale mineralogy did not have an impact on permeability. The permeability of clay-rich samples varied between 0.26 and 1.10 microdarcy. The permeability of calcite-rich samples varied between 0.18 and 2.05 microdarcy. Additionally, we found that the shale mineralogy affected the stress-dependent permeability. The magnitude of permeability reduction as a function of effective stress was dependent on the overall rock mineralogy. When the effective stress increased from 3.45 MPa to 13.79 MPa, the permeability of the clay-rich and calcite-rich samples decreased by 85% and 48%, respectively. Based on Klinkenberg analysis, we found that the mean effective pore radius for the clay-rich sample decreased from 27 nm at 3.45 MPa effective stress to 15 nm at 13.79 MPa effective stress (44% reduction). The mean effective pore radius for the calcite-rich sample decreased from 49 nm to 38 nm (22% reduction). These findings suggest that variations in rock mineralogy lead to different responses in mechanical deformation as the effective stress increases with depletion. Finally, our CO2 permeability measurements show that the CO2 permeability for the clay-rich sample decreased by 40% compared to Argon permeability. The CO2 permeability for the calcite-rich sample did not shift and was equivalent to

  18. Assessment of potential unconventional lacustrine shale-oil and shale-gas resources, Phitsanulok Basin, Thailand, 2014

    USGS Publications Warehouse

    Schenk, Christopher J.; Charpentier, Ronald R.; Klett, Timothy R.; Mercier, Tracey J.; Tennyson, Marilyn E.; Pitman, Janet K.; Brownfield, Michael E.

    2014-01-01

    Using a geology-based assessment methodology, the U.S. Geological Survey assessed potential technically recoverable mean resources of 53 million barrels of shale oil and 320 billion cubic feet of shale gas in the Phitsanulok Basin, onshore Thailand.

  19. Shale Gas: Development Opportunities and Challenges

    SciTech Connect

    Zoback, Mark D.; Arent, Douglas J.

    2014-03-01

    The use of horizontal drilling and multistage hydraulic fracturing technologies has enabled the production of immense quantities of natural gas, to date principally in North America but increasingly in other countries around the world. The global availability of this resource creates both opportunities and challenges that need to be addressed in a timely and effective manner. There seems little question that rapid shale gas development, coupled with fuel switching from coal to natural gas for power generation, can have beneficial effects on air pollution, greenhouse gas emissions, and energy security in many countries. In this context, shale gas resources represent a critically important transition fuel on the path to a decarbonized energy future. For these benefits to be realized, however, it is imperative that shale gas resources be developed with effective environmental safeguards to reduce their impact on land use, water resources, air quality, and nearby communities.

  20. Screening restimulation candidates in the Antrim Shale

    SciTech Connect

    Hopkins, C.W.; Frantz, J.H. Jr.; Tatum, C.L.; Hill, D.G.

    1994-12-31

    This paper describes a simple method to identify, prioritize, and evaluate restimulation candidates in the Antrim Shale of the Michigan Basin. This work is being performed as part of an ongoing field-based Gas Research Institute (GRI) project investigating the Antrim Shale. There are between 500 and 1,000 Antrim Shale wells which could be candidates for restimulation due to previous screenouts and/or flowback problems, when sand consolidation material was not used. However, all of these wells might not benefit from restimulation, due to either poor reservoir quality or because the wells are already effectively stimulated. Based on historical results, the authors estimate the increase in reserves from restimulation could be between 50 and 400 MMscf per well, which could add 50 to 200 Bscf in future reserves from the 500--1,000 candidate wells.

  1. Shale gas development: a smart regulation framework.

    PubMed

    Konschnik, Katherine E; Boling, Mark K

    2014-01-01

    Advances in directional drilling and hydraulic fracturing have sparked a natural gas boom from shale formations in the United States. Regulators face a rapidly changing industry comprised of hundreds of players, operating tens of thousands of wells across 30 states. They are often challenged to respond by budget cuts, a brain drain to industry, regulations designed for conventional gas developments, insufficient information, and deeply polarized debates about hydraulic fracturing and its regulation. As a result, shale gas governance remains a halting patchwork of rules, undermining opportunities to effectively characterize and mitigate development risk. The situation is dynamic, with research and incremental regulatory advances underway. Into this mix, we offer the CO/RE framework--characterization of risk, optimization of mitigation strategies, regulation, and enforcement--to design tailored governance strategies. We then apply CO/RE to three types of shale gas risks, to illustrate its potential utility to regulators.

  2. Thermal Maturation of Gas Shale Systems

    NASA Astrophysics Data System (ADS)

    Bernard, Sylvain; Horsfield, Brian

    2014-05-01

    Shale gas systems serve as sources, reservoirs, and seals for unconventional natural gas accumulations. These reservoirs bring numerous challenges to geologists and petroleum engineers in reservoir characterization, most notably because of their heterogeneous character due to depositional and diagenetic processes but also because of their constituent rocks' fine-grained nature and small pore size -- much smaller than in conventional sandstone and carbonate reservoirs. Significant advances have recently been achieved in unraveling the gaseous hydrocarbon generation and retention processes that occur within these complex systems. In addition, cutting-edge characterization technologies have allowed precise documentation of the spatial variability in chemistry and structure of thermally mature organic-rich shales at the submicrometer scale, revealing the presence of geochemical heterogeneities within overmature gas shale samples and, notably, the presence of nanoporous pyrobitumen. Such research advances will undoubtedly lead to improved performance, producibility, and modeling of such strategic resources at the reservoir scale.

  3. Rapid gas development in the Fayetteville shale basin, Arkansas

    EPA Science Inventory

    Advances in drilling and extraction of natural gas have resulted in rapid expansion of wells in shale basins. The rate of gas well installation in the Fayetteville shale is 774 wells a year since 2005 with thousands more planned. The Fayetteville shale covers 23,000 km2 although ...

  4. Oil shale extraction using super-critical extraction

    NASA Technical Reports Server (NTRS)

    Compton, L. E. (Inventor)

    1983-01-01

    Significant improvement in oil shale extraction under supercritical conditions is provided by extracting the shale at a temperature below 400 C, such as from about 250 C to about 350 C, with a solvent having a Hildebrand solubility parameter within 1 to 2 Hb of the solubility parameter for oil shale bitumen.

  5. Permeability Evolution of Shale and Coal Under Differential Sorption of He, CH4 And CO2

    NASA Astrophysics Data System (ADS)

    Kumar, H.; Elsworth, D.; Marone, C. J.; Mathews, J.

    2010-12-01

    Carbon dioxide injection in coal seams or in shales may be an option for geological sequestration of CO2 each with concurrent methane production. Permeability of the fractured porous medium is a crucial parameter influencing injectivity of CO2. The evolution of permeability is further complicated by dynamic changes in the coal/shale shrinkage/swelling with the reduction/increase in gas content. Complex geomechanical processes (transport of gas, adsorption, desorption, adjusting horizontal stresses and vertical strains) and chemical interaction between CO2, water and mineral matter content are some factors responsible for the various responses in permeability evolution. Adsorption of CO2 in micropores may result in matrix swelling therefore closing the existing natural fractures and lowering the ability of fluid flow. On the other hand presence of water may react with CO2 forming carbonic acid and removing carbonaceous mineral matter - either increasing or decreasing permeability. To address these issues we report experimental measurements of permeability evolution in shales infiltrated by helium, methane and carbon dioxide under varying pore pressure and deviatoric stresses. The role of gas (CO2 and CH4) adsorption and desorption under variable moisture contents and pore pressures have also been examined for sub-bituminous coals. Adsorption of CO2 in Coal and shale reduces the reservoir permeability even when the fractured media are mechanically unconstrained. However we found that permeability loss is temporary. In the specific case of Marcellus shale, adsorption of CO2 in the sample reduces the permeability to half the original value. Permeability values returns to its original value if sample is allowed to interact for sufficient time. Variation of permeability with deviotoric stress suggests the compaction band formation above a threshold value of stress. These deformations are permanent and shale loses its permeability. Several observations on permeability

  6. Shale seismic anisotropy vs. compaction trend

    NASA Astrophysics Data System (ADS)

    Pervukhina, M.

    2015-12-01

    Shales comprise more than 60% of sedimentary rocks and form natural seals above hydrocarbon reservoirs. Their sealing capacity is also used for storage of nuclear wastes. Shales are notorious for their strong elastic anisotropy, so-called, vertical transverse isotropy or VTI. This VTI anisotropy is of practical importance as it is required for correct surface seismic data interpretation, seismic to well tie and azimuth versus offset analysis. A number of competing factors are responsible for VTI anisotropy in shales, namely, (1) micro-scale elastic anisotropy of clay particles, (2) anisotropic orientation distribution function of clay particles, (3) anisotropic orientation of pores and organic matter. On the contrary, silt (non-clay mineralogy grains with size between 0.06 -0.002 mm) is known to reduce elastic anisotropy of shales. Methods developed for calculations of anisotropy in polycrystalline materials can be used to estimate elastic anisotropy of shales from orientation distribution function (ODF) of clay platelets if elastic properties of individual clay platelets are known. Unfortunately, elastic properties of individual clay platelets cannot be directly measured. Recently, elastic properties of properties of individual clay platelets with different mineralogy were calculated from first principles based on density functional theory. In this work we use these elastic properties of individual platelets of muscovite, illite-smectite and kaolinite to obtain correlations between elastic anisotropy and Legendre coefficients W200 and W400 of different ODFs. Comparison of the Legendre coefficients calculated for more than 800 shales from depths 0 - 6 km (www.rockphysicists.org/data) with those of compaction ODFs shows that compaction has no first order effect on elastic anisotropy. Thus, elastic anisotropy is to large extent determined by factors other than compaction processes, such as depositional environment, chemical composition of fluid, silt fraction, etc.

  7. Kinetics of oil shale char gasification

    SciTech Connect

    Thomson, W.J.; Gerber, M.A.; Hatter, M.A.; Oakes, D.G.

    1981-01-01

    The kinetics of oil shale char gasification have been studied for Colorado oil shale from the Parachute Creek member. Reaction rate expressions similar to those previously reported for coal char were obtained for the H/sub 2/O-char, CO/sub 2/-char, and water gas shift reactions. Evidence is presented to suggest that CaO, a product of mineral decomposition, catalyzes the H/sub 2/O-char reaction and that indigenous iron catalyzes the water gas shift reaction. The latter reaction proceeds rapidly so that the make-gas consists primarily of H/sub 2/ and CO/sub 2/. 12 references.

  8. Veining Failure and Hydraulic Fracturing in Shales

    NASA Astrophysics Data System (ADS)

    Mighani, S.; Sondergeld, C. H.; Rai, C. S.

    2014-12-01

    During the hydraulic fracturing, the pressurized fluid creates new fractures and reactivates existing natural fractures forming a highly conductive Stimulated Reservoir Volume (SRV) around the borehole. We extend the previous work on Lyons sandstone and pyrophyllite to anisotropic shale from the Wolfcamp formation. We divide the rock anisotropy into two groups: a) conventional and b) unconventional (shaly) anisotropy. X-ray Computed Tomography (CT), compressional velocity anisotropy, and SEM analysis are used to identify three causes of anisotropy: bedding planes, clay lamination, and calcite veins. Calcite vein is a subsequently filled with calcite bonded weakly to the matrix. Velocity anisotropy and visual observations demonstrate the calcite filled veins to be mostly subparallel to the fabric direction. Brazilian tests are carried out to observe the fracture initiation and propagation under tension. High speed photography (frame rate 300,000 frame/sec) was used to capture the failure. Strain gauges and Acoustic Emission (AE) sensors recorded the deformation leading up to and during failure. SEM imaging and surface profilometry were employed to study the post-failure fracture system and failed surface topology. Fracture permeability was measured as a function of effective stress. Brazilian tests on small disks containing a centered single vein revealed the shear strength of the veins. We interpret the strain data and number, frequency, and amplitude of AE events which are correlated well with the observed fracture process zone, surface roughness, and permeability. The unpropped fracture has enhanced permeability by two orders of magnitude. The observed anisotropic tensile failure seems to have a universal trend with a minimum strength occurring at 15o orientation with respect to the loading axis. The veins at 15o orientation with respect to the loading axis were easily activated at 30% of the original failure load. The measured strength of the vein is as low as 6

  9. Shale volume determination using sonic, density and neutron data

    NASA Astrophysics Data System (ADS)

    Mabrouk, Walid M.; Kamel, Mostafa H.

    2011-06-01

    The volume of shale calculation based on naturally occurring gamma rays frequently overestimates shale volume when radioactive material other than shale is present, for example where sand appears to be shale. In this situation, shale volume calculations from other methods are highly recommended in order to avoid overestimation or underestimation of shale volume. This paper introduces an equation relating shale volume to porosity logs (neutron, density and acoustic logs), which takes into account the effect of matrix, fluid and shale parameters. This equation, which is based on the effective porosity definition and the Dresser Atlas (1982) equation, has been successfully applied to many shaly formations, regardless of the type and distribution of shale. Solved examples are used to test and compare this equation and the results come close to what actually exists, with the amount of error ranging from -5 to +5%. The advantages of the proposed equation can be summarised as: (1) it is a function of several parameters that affect the determination of shale volume in one formula; (2) it collects the three porosity tools for a more accurate calculation; and (3) it works best where radioactive material other than shale is present.

  10. Studies of New Albany shale in western Kentucky. Final report

    SciTech Connect

    Schwalb, H.R.; Norris, R.L.

    1980-02-01

    The New Albany (Upper Devonian) Shale in western Kentucky can be zoned by using correlative characteristics distinguishable on wire-line logs. Wells drilled through the shale which were logged by various methods provided a basis for zonation of the subsurface members and units of the Grassy Creek, Sweetland Creek, and Blocher. Structure and isopach maps and cross sections were prepared. The Hannibal Shale and Rockford Limestone were found in limited areas; isopach maps were not made for these members. Samples of cuttings from selected wells were studied in order to identify the contact of the shale with underlying and overlying rock units. A well-site examination of cuttings through the shale section was conducted, and the presence of natural gas was observed in the field. The New Albany Shale has the potential for additional commercially marketable natural gas production. Exploratory drilling is needed to evaluate the reservoir characteristics of the New Albany Shale.

  11. Experimental Investigation into Hydraulic Fracture Network Propagation in Gas Shales Using CT Scanning Technology

    NASA Astrophysics Data System (ADS)

    Yushi, Zou; Shicheng, Zhang; Tong, Zhou; Xiang, Zhou; Tiankui, Guo

    2016-01-01

    Multistage fracturing of the horizontal well is recognized as the main stimulation technology for shale gas development. The hydraulic fracture geometry and stimulated reservoir volume (SRV) is interpreted by using the microseismic mapping technology. In this paper, we used a computerized tomography (CT) scanning technique to reveal the fracture geometry created in natural bedding-developed shale (cubic block of 30 cm × 30 cm × 30 cm) by laboratory fracturing. Experimental results show that partially opened bedding planes are helpful in increasing fracture complexity in shale. However, they tend to dominate fracture patterns for vertical stress difference Δ σ v ≤ 6 MPa, which decreases the vertical fracture number, resulting in the minimum SRV. A uniformly distributed complex fracture network requires the induced hydraulic fractures that can connect the pre-existing fractures as well as pulverize the continuum rock mass. In typical shale with a narrow (<0.05 mm) and closed natural fracture system, it is likely to create complex fracture for horizontal stress difference Δ σ h ≤ 6 MPa and simple transverse fracture for Δ σ h ≥ 9 MPa. However, high naturally fractured shale with a wide open natural fracture system (>0.1 mm) does not agree with the rule that low Δ σ h is favorable for uniformly creating a complex fracture network in zone. In such case, a moderate Δ σ h from 3 to 6 MPa is favorable for both the growth of new hydraulic fractures and the activation of a natural fracture system. Shale bedding, natural fracture, and geostress are objective formation conditions that we cannot change; we can only maximize the fracture complexity by controlling the engineering design for fluid viscosity, flow rate, and well completion type. Variable flow rate fracturing with low-viscosity slickwater fluid of 2.5 mPa s was proved to be an effective treatment to improve the connectivity of induced hydraulic fracture with pre-existing fractures. Moreover, the

  12. [Chemical hazards arising from shale gas extraction].

    PubMed

    Pakulska, Daria

    2015-01-01

    The development of the shale industry is gaining momentum and hence the analysis of chemical hazards to the environment and health of the local population is extreiely timely and important. Chemical hazards are created during the exploitation of all minerals, but in the case of shale gas production, there is much more uncertainty as regards to the effects of new technologies application. American experience suggests the increasing risk of environmental contamination, mainly groundwater. The greatest, concern is the incomplete knowledge of the composition of fluids used for fracturing shale rock and unpredictability of long-term effects of hydraulic fracturing for the environment and health of residents. High population density in the old continent causes the problem of chemical hazards which is much larger than in the USA. Despite the growing public discontent data on this subject are limited. First of all, there is no epidemiological studies to assess the relationship between risk factors, such as air and water pollution, and health effects in populations living in close proximity to gas wells. The aim of this article is to identify and discuss existing concepts on the sources of environmental contamination, an indication of the environment elements under pressure and potential health risks arising from shale gas extraction.

  13. [Chemical hazards arising from shale gas extraction].

    PubMed

    Pakulska, Daria

    2015-01-01

    The development of the shale industry is gaining momentum and hence the analysis of chemical hazards to the environment and health of the local population is extreiely timely and important. Chemical hazards are created during the exploitation of all minerals, but in the case of shale gas production, there is much more uncertainty as regards to the effects of new technologies application. American experience suggests the increasing risk of environmental contamination, mainly groundwater. The greatest, concern is the incomplete knowledge of the composition of fluids used for fracturing shale rock and unpredictability of long-term effects of hydraulic fracturing for the environment and health of residents. High population density in the old continent causes the problem of chemical hazards which is much larger than in the USA. Despite the growing public discontent data on this subject are limited. First of all, there is no epidemiological studies to assess the relationship between risk factors, such as air and water pollution, and health effects in populations living in close proximity to gas wells. The aim of this article is to identify and discuss existing concepts on the sources of environmental contamination, an indication of the environment elements under pressure and potential health risks arising from shale gas extraction. PMID:26016049

  14. Antrim shale bibliography. Topical report, June 1993

    SciTech Connect

    Picciano, L.; Armstrong, T.

    1993-06-01

    The report lists almost one hundred publications on research and exploration in the Antrim Shale. The bibliography includes reports, journal articles, meeting and symposium proceedings, and other types of publications from various sources including: Gas Research Institute, Society of Petroleum Engineers, U.S. Department of Energy, and American Association of Petroleum Geologists.

  15. Technically recoverable Devonian shale gas in Ohio

    SciTech Connect

    Kuushraa, V.A.; Wicks, D.E.; Sawyer, W.K.; Esposito, P.R.

    1983-07-01

    The technically recoverable gas from Devonian shale (Lower and Middle Huron) in Ohio is estimated to range from 6.2 to 22.5 Tcf, depending on the stimulation method and pattern size selected. This estimate of recovery is based on the integration of the most recent data and research on the Devonian Age gas-bearing shales of Ohio. This includes: (1) a compilation of the latest geologic and reservoir data for the gas in-place; (2) analysis of the key productive mechanisms; and, (3) examination of alternative stimulation and production strategies for most efficiently recovering this gas. Beyond a comprehensive assembly of the data and calculation of the technically recoverable gas, the key findings of this report are as follows: a substantial volume of gas is technically recoverable, although advanced (larger scale) stimulation technology will be required to reach economically attractive gas production rates in much of the state; well spacing in certain of the areas can be reduced by half from the traditional 150 to 160 acres per well without severely impairing per-well gas recovery; and, due to the relatively high degree of permeability anisotropy in the Devonian shales, a rectangular, generally 3 by 1 well pattern leads to optimum recovery. Finally, although a consistent geological interpretation and model have been constructed for the Lower and Middle Huron intervals of the Ohio Devonian shale, this interpretation is founded on limited data currently available, along with numerous technical assumptions that need further verification. 11 references, 21 figures, 32 tables.

  16. Developments in oil shale in 1986

    SciTech Connect

    Knutson, C.F.; Dana, G.F.; Solti, G.; Hutton, A.C.; Russell, P.L.; Macanley, G.; Piper, E.M.

    1987-01-01

    Oil shale project development continued at a slow pace in the USA. The Unocal project in the Piceance Basin, Colorado achieved projection at the 4000 to 5000 bbl/day (639 to 795 m/sup 3//day) rate. Production and project development continued in the USSR, Central, Europe, the Circum - Mediterranean area and in Australia. 17 refs., 5 figs., 3 tabs.

  17. Geochemical controls on groundwater chemistry in shales

    SciTech Connect

    Von Damm, K.L.

    1989-01-01

    The chemistry of groundwaters is one of the most important parameters in determining the mobility of species within a rock formation. A three pronged approach was used to determine the composition of, and geochemical controls, on groundwaters specifically within shale formations: (1) available data were collected from the literature, the US Geological Survey WATSTORE data base, and field sampling, (2) the geochemical modeling code EQ3/6 was used to simulate interaction of various shales and groundwaters, and (3) several types of shale were reacted with synthetic groundwaters in the laboratory. The comparison of model results to field and laboratory data provide a means of validating the models, as well as a means of deconvoluting complex field interactions. Results suggest that groundwaters in shales have a wide range in composition and are primarily of the Na-Cl-HCO/sub 3/- type. The constancy of the Na:Cl (molar) ratio at 1:1 and the Ca:Mg ratio from 3:1 to 1:1 suggests the importance of halite and carbonates in controlling groundwater compositions. In agreement with the reaction path modeling, most of the groundwaters are neutral to slightly alkaline at low temperatures. Model and experimental results suggest that reaction (1) at elevated temperatures, or (2) in the presence of oxygen will lead to more acidic conditions. Some acetate was found to be produced in the experiments; depending on the constraints applied, large amounts of acetate were produced in the model results. 13 refs., 1 tab.

  18. Naturally occurring contamination in the Mancos Shale.

    PubMed

    Morrison, Stan J; Goodknight, Craig S; Tigar, Aaron D; Bush, Richard P; Gil, April

    2012-02-01

    Some uranium mill tailings disposal cells were constructed on dark-gray shale of the Upper Cretaceous Mancos Shale. Shale of this formation contains contaminants similar to those in mill tailings. To establish the contributions derived from the Mancos, we sampled 51 locations in Colorado, New Mexico, and Utah. Many of the groundwater samples were saline with nitrate, selenium, and uranium concentrations commonly exceeding 250, 000, 1000, and 200 μg/L, respectively. Higher concentrations were limited to groundwater associated with shale beds, but were not correlated with geographic area, stratigraphic position, or source of water. The elevated concentrations suggest that naturally occurring contamination should be considered when evaluating groundwater cleanup levels. At several locations, seep water was yellow or red, caused in part by dissolved organic carbon concentrations up to 280 mg/L. Most seeps had (234)U to (238)U activity ratios greater than 2, indicating preferential leaching of (234)U. Seeps were slightly enriched in (18)O relative to the meteoric water line, indicating limited evaporation. Conceptually, major ion chemical reactions are dominated by calcite dissolution following proton release from pyrite oxidation and subsequent exchange by calcium for sodium residing on clay mineral exchange sites. Contaminants are likely released from organic matter and mineral surfaces during weathering.

  19. Boomtown blues; Oil shale and Exxon's exit

    SciTech Connect

    Gulliford, A. )

    1989-01-01

    This paper chronicles the social and cultural effects of the recent oil shale boom on the Colorado communities of Rifle, Silt, Parachute, and Grand Junction. The paper is based upon research and oral history interviews conducted throughout Colorado and in Houston and Washington, DC.

  20. Pore-scale studies of gas shale

    NASA Astrophysics Data System (ADS)

    Silin, D.; Ajo Franklin, J. B.; Cabrini, S.; Kneafsey, T. J.; MacDowell, A.; Nico, P. S.; Radmilovic, V.

    2010-12-01

    Natural gas is the cleanest hydrocarbon fuel. The contribution of natural gas produced from shale to the United States energy portfolio has been steadily increasing over the past several years. The projections into the coming decades expect this trend to remain stable. Although the advancements in well stimulation technologies have made it possible to convert huge resources into recoverable reserves, the mechanisms of gas recovery from these practically impermeable rocks are not yet fully understood. We employed the powerful imaging facilities at Lawrence Berkeley National Laboratory to gain insights into the pore geometry and structure of shale at micron and submicron scales. The X-ray micro-tomography facility at the Advanced Light Source produces 3D reconstructions of the pore space at resolutions approaching one micron. The Focused Ion-Beam sequential milling and imaging at the Molecular Foundry and National Center for Electron Microscopy allows for 3D shale structure and mineral composition at a resolution on the order of ten nanometers. We find that even a miniscule volume of reservoir shale includes an extremely rich diversity of minerals and geometries. Organic matter is consistently present as pore filling among solid grains. Some samples show a connected networks of pores in kerogen, apparently indicating its thermal maturity. Understanding the features controlling gas flow will help increase the ultimate recovery and extend the productive lifetime of a given well.

  1. Evaluation of RA tracer surveys and hydraulic fracture ID logs in the Antrim shale. Topical report, June-August 1993

    SciTech Connect

    Reeves, S.R.; Wicks, D.E.

    1993-11-01

    The report summarizes the results of five radioactive tracer surveys, one comparison of pre- and post-stimulation fracture identification logs, and presents stress/mechanical properties information from three wells in the Antrim Shale of the Michigan Basin. The purpose of this work, based on wells located in Section 29, 31 and 32 of T3ON, R1W, and in Section 17 of T29N, R1W, was to provide insights into fracture growth behavior in the Antrim Shale. While highly interpretive and conflicting at times, the data seem to suggest (1) that both the Lachine and Norwood shales are fractured during single-stage treatements, (2) that the Paxton appears to be a good fracture barrier, (3) fracture height growth into the Ellsworth is possible when the Lachine is stimulated, and (4) discreet vertical intervals of fracturing occur in the Lachine as opposed to a single, continuous vertical fracture over the entire interval.

  2. Geology of the Devonian black shales of the Appalachian basin

    USGS Publications Warehouse

    Roen, J.B.

    1983-01-01

    Black shales of Devonian age in the Appalachian basin are a unique rock sequence. The high content of organic matter, which imparts the characteristic lithology, has for years attracted considerable interest in the shales as a possible source of energy. Concurrent with periodic and varied economic exploitations of the black shales are geologic studies. The recent energy shortage prompted the U.S. Department of Energy through the Eastern Gas Shales Project of the Morgantown Energy Technology Center to underwrite a research program to determine the geologic, geochemical, and structural characteristics of the Devonian black shales in order to enhance the recovery of gas from the shales. Geologic studies produced a regional stratigraphic network that correlates the 15-foot sequence in Tennessee with 3,000 feet of interbedded black and gray shales in central New York. The classic Devonian black-shale sequence in New York has been correlated with the Ohio Shale of Ohio and Kentucky and the Chattanooga Shale of Tennessee and southwestern Virginia. Biostratigraphic and lithostratigraphic markers in conjunction with gamma-ray logs facilitated long range correlations within the Appalachian basin and provided a basis for correlations with the black shales of the Illinois and Michigan basins. Areal distribution of selected shale units along with paleocurrent studies, clay mineralogy, and geochemistry suggests variations in the sediment source and transport directions. Current structures, faunal evidence, lithologic variations, and geochemical studies provide evidence to support interpretation of depositional environments. In addition, organic geochemical data combined with stratigraphic and structural characteristics of the shale within the basin allow an evaluation of the resource potential of natural gas in the Devonian shale sequence.

  3. Oil shale development and its environmental considerations

    USGS Publications Warehouse

    Stone, R.T.; Johnson, H.; Decora, A.

    1974-01-01

    The petroleum shortage recently experienced by many nations throughout the world has created an intense interest in obtaining new and supplemental energy sources. In the United States, this interest has been centered on oil shale. Any major action by the federal government having significant environmental effects requires compliance with the National Environmental Policy Act of 1969 (NEPA). Since most oil shale is found on federal lands, and since its development involves significant environmental impacts, leasing oil shale lands to private interests must be in compliance with NEPA. For oil shale, program planning began at approximately the same time that NEPA was signed into law. By structuring the program to permit a resource and technological inventory by industry and the federal agencies, the Department of the Interior was able simultaneously to conduct the environmental assessments required by the act. This required: 1. Clearly defined program objections; 2. An organization which could integrate public policy with diverse scientific disciplines and environmental concerns; and 3. Flexible decisionmaking to adjust to policy changes as well as to evolving interpretations on EPA as clarified by court decisions. This paper outlines the program, the organization structure that was created for this specific task, and the environmental concerns which were investigated. The success of the program has been demonstrated by meeting the requirements of NEPA, without court challenge, and by industry's acceptance of a leasing program that included the most stringent environmental protection provisions ever required. The need for energy development has spurred the acceptance of the program. However, by its awareness and willingness to meet the environmental challenges of the future, industry has shown a reasonable understanding of its commitments. The pros and cons of development were publicly considered in hearings and analyzed in the final environmental statement. This

  4. Size reduction of Green River shale

    SciTech Connect

    Salotti, C.A.; Datta, R.S.

    1983-04-01

    Closely controlled size reduction of Green River shale is a necessary preliminary step in evaluating the use of heavy media cycloning in shale beneficiation. A series of crushing tests was run to evaluate quantitatively Green River shale products after similar processing through crushers of diverse designs. Two separate 200-ton samples of C-a shale were collected in Rio Blanco's mine from the R-6 (20.7 GPT) and from the R-5 (24.9 GPT) zones (Figure 1). These samples were transported to the Colorado School of Mines Research Institute (CSMRI) where they were carefully mixed and each separated into two 100-ton lots. One hundred tons of each sample were screened into the following sizes: 6'' x 3''; 3'' x 1-1/2''; 1-1/2'' x 3/4''; 3/4'' x 3/8''; 3/8'' x 8M; 8M x 28M; 28M x 100M; and 100M x 0. Two, approximately 10-ton lots each of 6'' x 3'' and 3'' x 3/8'' material from the screened and sized run-of-mine shale, were sent to three crushing equipment manufacturers for comparative crushing tests. Three types of crushers were evaluated: gyratory cone crushers; impact crushers; and roll crushers. The above size fractions were crushed to 3'', 1-1/2'', 3/4'', and 3/8'' top sizes. The sizes were screened into +3'', -3'', -1-1/2'', 1-1/2'', -3/4'', 3/4'', -3/8'', 3/8'', -28M, 28M, -100M, and 100M size fractions. Each fraction was sampled, Fischer Assayed, and grade-particle size relations determined for each crusher product.

  5. Mechanical properties of heavy oil-sand and shale as a function of pressure and temperature

    SciTech Connect

    Blair, S.C.; Sweeney, J.J.; Ralph, W.R.; Ruddle, D.G.

    1987-07-01

    Laboratory tests were conducted to determine the mechanical properties of oil-sand and shale samples from the Faja region of Venezuela at elevated temperature and pressure. Results describe pressure-volume (PV) behavior at temperatures of 23 and 125/sup 0/C; the effect of mechanical disturbance on PV behavior; equation-of-state (EOS) at temperatures of 23, 125, and 250/sup 0/C and effective pressures to 150 MPa; and creep/compaction behavior at temperatures of 23 and 125/sup 0/C. Data from PV tests on oil-sand show that increasing temperature from 23 to 125/sup 0/C had very little effect on this material. Mechanical disturbance of oil-sand prior to PV testing lowered values of K. The compressive strength of oil-sand increased as effective (P/sub E/) was raised and at both temperatures, samples tested at equivalent P/sub E/ had similar strengths. Compressive strength of oil-sand seems to be controlled by the drainage of pore fluid during axial deformation. Nearly all oil-sand samples exhibited strain-hardening. PV tests conducted on shale show that increasing temperature from 23 to 125/sup 0/C reduced values of K one third. Mechanical disturbance significantly affected the PV response of shale samples due to the friable nature of the material. Data for shale samples tested in triaxial compression show that ultimate stress increases with increasing pressure and increasing temperature. Results of long-term creep compaction tests show a linear change in sample volume as a function of the log of time and that the rate of volume change with time was larger at 125/sup 0/C than at 23/sup 0/C for both oil-sand and shale. 4 refs., 31 figs., 6 tabs.

  6. Western Greece unconventional hydrocarbon potential from oil shale and shale gas reservoirs

    NASA Astrophysics Data System (ADS)

    Karakitsios, Vasileios; Agiadi, Konstantina

    2013-04-01

    It is clear that we are gradually running out of new sedimentary basins to explore for conventional oil and gas and that the reserves of conventional oil, which can be produced cheaply, are limited. This is the reason why several major oil companies invest in what are often called unconventional hydrocarbons: mainly oil shales, heavy oil, tar sand and shale gas. In western Greece exist important oil and gas shale reservoirs which must be added to its hydrocarbon potential1,2. Regarding oil shales, Western Greece presents significant underground immature, or close to the early maturation stage, source rocks with black shale composition. These source rock oils may be produced by applying an in-situ conversion process (ICP). A modern technology, yet unproven at a commercial scale, is the thermally conductive in-situ conversion technology, developed by Shell3. Since most of western Greece source rocks are black shales with high organic content, those, which are immature or close to the maturity limit have sufficient thickness and are located below 1500 meters depth, may be converted artificially by in situ pyrolysis. In western Greece, there are several extensive areas with these characteristics, which may be subject of exploitation in the future2. Shale gas reservoirs in Western Greece are quite possibly present in all areas where shales occur below the ground-water level, with significant extent and organic matter content greater than 1%, and during their geological history, were found under conditions corresponding to the gas window (generally at depths over 5,000 to 6,000m). Western Greece contains argillaceous source rocks, found within the gas window, from which shale gas may be produced and consequently these rocks represent exploitable shale gas reservoirs. Considering the inevitable increase in crude oil prices, it is expected that at some point soon Western Greece shales will most probably be targeted. Exploration for conventional petroleum reservoirs

  7. The Antrim Shale: Structural and stratigraphic influences on gas production

    SciTech Connect

    Manger, K.C.; Oliver, S.J.P. ); Scheper, R.J. )

    1991-03-01

    The Antrim Shale of the Michigan basin is one of the most actively drilled gas plays in the United States. Core analysis, geologic mapping, and core to log correlations of a 9 mi{sup 2} study area in the middle of the present play have defined geologic influences on the location and productivity of Antrim reservoirs. Application of these factors in the design of exploration and development strategies could improve gas recovery from the Antrim Shale. The lower section of the Antrim Shale, containing the present producing horizons, is composed of four lithologies that subdivide the Antrim into facies and parasequences based upon their mineralogy and textural characteristics. The black shales of the producing horizons are characterized by high but variable quartz contents and an extremely fine-grained matrix of muscovite and clays. The black shales are surrounded by two types of gray shale, differentiated by amount and form of carbonates, and a green shale. The type of shale bounding the productive, organic-rich black shales may affect stimulation strategies and their effectiveness. These black shales average 10% but can be as high as 20% TOC by weight. The organic contents impart a distinctive signature to gamma ray logs that enabled isopach, lithofacies, and structural mapping of the Antrim. Correlated with available production data, the maps reveal distinct trends suggesting that well performance is influenced by both structural and stratigraphic controls.

  8. Shale gas development impacts on surface water quality in Pennsylvania

    PubMed Central

    Olmstead, Sheila M.; Muehlenbachs, Lucija A.; Shih, Jhih-Shyang; Chu, Ziyan; Krupnick, Alan J.

    2013-01-01

    Concern has been raised in the scientific literature about the environmental implications of extracting natural gas from deep shale formations, and published studies suggest that shale gas development may affect local groundwater quality. The potential for surface water quality degradation has been discussed in prior work, although no empirical analysis of this issue has been published. The potential for large-scale surface water quality degradation has affected regulatory approaches to shale gas development in some US states, despite the dearth of evidence. This paper conducts a large-scale examination of the extent to which shale gas development activities affect surface water quality. Focusing on the Marcellus Shale in Pennsylvania, we estimate the effect of shale gas wells and the release of treated shale gas waste by permitted treatment facilities on observed downstream concentrations of chloride (Cl−) and total suspended solids (TSS), controlling for other factors. Results suggest that (i) the treatment of shale gas waste by treatment plants in a watershed raises downstream Cl− concentrations but not TSS concentrations, and (ii) the presence of shale gas wells in a watershed raises downstream TSS concentrations but not Cl− concentrations. These results can inform future voluntary measures taken by shale gas operators and policy approaches taken by regulators to protect surface water quality as the scale of this economically important activity increases. PMID:23479604

  9. Shale gas development impacts on surface water quality in Pennsylvania.

    PubMed

    Olmstead, Sheila M; Muehlenbachs, Lucija A; Shih, Jhih-Shyang; Chu, Ziyan; Krupnick, Alan J

    2013-03-26

    Concern has been raised in the scientific literature about the environmental implications of extracting natural gas from deep shale formations, and published studies suggest that shale gas development may affect local groundwater quality. The potential for surface water quality degradation has been discussed in prior work, although no empirical analysis of this issue has been published. The potential for large-scale surface water quality degradation has affected regulatory approaches to shale gas development in some US states, despite the dearth of evidence. This paper conducts a large-scale examination of the extent to which shale gas development activities affect surface water quality. Focusing on the Marcellus Shale in Pennsylvania, we estimate the effect of shale gas wells and the release of treated shale gas waste by permitted treatment facilities on observed downstream concentrations of chloride (Cl(-)) and total suspended solids (TSS), controlling for other factors. Results suggest that (i) the treatment of shale gas waste by treatment plants in a watershed raises downstream Cl(-) concentrations but not TSS concentrations, and (ii) the presence of shale gas wells in a watershed raises downstream TSS concentrations but not Cl(-) concentrations. These results can inform future voluntary measures taken by shale gas operators and policy approaches taken by regulators to protect surface water quality as the scale of this economically important activity increases.

  10. Water management practices used by Fayetteville shale gas producers.

    SciTech Connect

    Veil, J. A.

    2011-06-03

    Water issues continue to play an important role in producing natural gas from shale formations. This report examines water issues relating to shale gas production in the Fayetteville Shale. In particular, the report focuses on how gas producers obtain water supplies used for drilling and hydraulically fracturing wells, how that water is transported to the well sites and stored, and how the wastewater from the wells (flowback and produced water) is managed. Last year, Argonne National Laboratory made a similar evaluation of water issues in the Marcellus Shale (Veil 2010). Gas production in the Marcellus Shale involves at least three states, many oil and gas operators, and multiple wastewater management options. Consequently, Veil (2010) provided extensive information on water. This current study is less complicated for several reasons: (1) gas production in the Fayetteville Shale is somewhat more mature and stable than production in the Marcellus Shale; (2) the Fayetteville Shale underlies a single state (Arkansas); (3) there are only a few gas producers that operate the large majority of the wells in the Fayetteville Shale; (4) much of the water management information relating to the Marcellus Shale also applies to the Fayetteville Shale, therefore, it can be referenced from Veil (2010) rather than being recreated here; and (5) the author has previously published a report on the Fayetteville Shale (Veil 2007) and has helped to develop an informational website on the Fayetteville Shale (Argonne and University of Arkansas 2008), both of these sources, which are relevant to the subject of this report, are cited as references.

  11. Geology of the Devonian black shales of the Appalachian Basin

    USGS Publications Warehouse

    Roen, J.B.

    1984-01-01

    Black shales of Devonian age in the Appalachian Basin are a unique rock sequence. The high content of organic matter, which imparts the characteristic lithology, has for years attracted considerable interest in the shales as a possible source of energy. The recent energy shortage prompted the U.S. Department of Energy through the Eastern Gas Shales Project of the Morgantown Energy Technology Center to underwrite a research program to determine the geologic, geochemical, and structural characteristics of the Devonian black shales in order to enhance the recovery of gas from the shales. Geologic studies by Federal and State agencies and academic institutions produced a regional stratigraphic network that correlates the 15 ft black shale sequence in Tennessee with 3000 ft of interbedded black and gray shales in central New York. These studies correlate the classic Devonian black shale sequence in New York with the Ohio Shale of Ohio and Kentucky and the Chattanooga Shale of Tennessee and southwestern Virginia. Biostratigraphic and lithostratigraphic markers in conjunction with gamma-ray logs facilitated long-range correlations within the Appalachian Basin. Basinwide correlations, including the subsurface rocks, provided a basis for determining the areal distribution and thickness of the important black shale units. The organic carbon content of the dark shales generally increases from east to west across the basin and is sufficient to qualify as a hydrocarbon source rock. Significant structural features that involve the black shale and their hydrocarbon potential are the Rome trough, Kentucky River and Irvine-Paint Creek fault zone, and regional decollements and ramp zones. ?? 1984.

  12. Rock Springs Site 12 hydraulic/explosive true in situ oil shale fracturing experiment

    SciTech Connect

    Parrish, R.L.; Boade, R.R.; Stevens, A.L.; Long, A. Jr.; Turner, T.F.

    1980-06-01

    The experiment plan involved the creation and characterization of three horizontal hydraulic fractures, followed by the insertion and simultaneous detonation of slurry explosive in the two lower fractures. Core analyses, wellbore logging, and airflow and /sup 85/Kr tracer tests were used for site characterization and assessment of the hydraulic and explosive fracturing. Tiltmeters, wellhead pressure and flow gages, and in-formation pressure, flow and crack-opening sensors were used to monitor hydrofracture creation and explosive insertion. Explosive detonation diagnostic data were taken with stress and time-of-arrival gages and surface and in-formation accelerometers. The post-fracturing assessments indicated that: (1) hydrofracture creation and explosive insertion and detonation were accomplished essentially as planned; (2) induced fractures were randomly distributed through the shale with no extensively fractured regions or dislocation of shale; and (3) enhancement of permeability was limited to enlargement of the explosive-filled fractures.

  13. Influence of mobile shale on thrust faults: Insights from discrete element simulations

    NASA Astrophysics Data System (ADS)

    Dean, S. L.; Morgan, J. K.

    2013-12-01

    We use two-dimensional discrete element method (DEM) simulations to study the effects of a two-layer mechanical stratigraphy on a gravitationally collapsing passive margin. The system consists of an upslope sedimentary wedge, overlying an extensional zone that is linked at depth with a downslope fold and thrust belt. The behavior of the system is dependent on the material properties and thickness of the competent units. The models are initially composed of a mobile shale unit overlain by a pre-delta unit. In DEM materials, the bulk rheology of the granular material is a product of the particle interactions, depending on a range of parameters, including friction and elastic moduli. Natural mobile shales underlying deltas are presumed to be viscous, and are therefore represented in DEM as very weak non-cohesive particles. The unbonded particles respond to loading by moving to areas of lower stress, i.e. out from beneath a growing sediment wedge. The bulk motion of the particles therefore flows away from the upslope extensional zone. Apparent viscosity is introduced in DEM materials due to time dependent numerical parameters such as viscous damping of particle motions. We characterized this apparent viscosity of this mobile shale unit with a series of shear box tests, with varying shear strain rates. The mobile shale particles have a viscosity of about 108 Pa*s, which is low for mobile shale. The low viscosity of our numerical materials can be compensated for by scaling time in our models, because the simulations are driven by sedimentary loading. By increasing the sedimentation rate by many orders of magnitude, we can approximate the natural values of shear stress in our simulations. Results are compared with the Niger Delta type locale for shale tectonics. The simulations succeed in creating an overall linked extensional-contractional system, as well as creating individual structures such as popups and intersecting forethrusts and backthrusts. In addition, toe

  14. Volume 9: A Review of Socioeconomic Impacts of Oil Shale Development WESTERN OIL SHALE DEVELOPMENT: A TECHNOLOGY ASSESSMENT

    SciTech Connect

    Rotariu, G. J.

    1982-02-01

    services and programs designed to relieve stress, to provide a sense of community, and to integrate newcomers into the community may alleviate some of the negative consequences of rapid social change. In Sec. VII, we examine the factors that lead to social disruption and other negative consequences of social change in western rural communities. The importance of policy as a variable affecting social impacts is also discussed. State and local governments have recognized the need to plan for growth although there continues to be much skepticism with regard to oil shale development. The planning activities of these governments are described in Sec. VIII. In addition to the development of comprehensive land use plans, local governments have developed mechanisms to define community needs. To prepare for growth that was forecasted for the late 1970s, local governments have obtained financial assistance from state and Federal programs to upgrade existing water and sewer systems, streets, schools, and other public facilities. Consequently, some of the communities in the region have excess capacity in their water and sewage treatment facilities and in their schools. There is a great reliance on external financial assistance for the construction of major public facilities that places heavy burdens of grantsmanship on local governments.

  15. Reverse engineering mother nature — Shale sedimentology from an experimental perspective

    NASA Astrophysics Data System (ADS)

    Schieber, Juergen

    2011-06-01

    Experimental study of the sedimentology of shales can take a variety of forms. At its simplest one can experiment with suspensions in a glass jar and try to understand their settling behavior, or one can manipulate mud in a tank or bucket to gain insights into its rheology. This approach was championed over a century ago by Sorby, and the insights gained can be quite profound. More recently, tank and settling tube experiments of animal-sediment interactions, compaction behavior, and sediment unmixing via re-suspension have proven to be highly informative in spite of their simplicity. Flumes can be used to obtain quantitative information about depositional and erosional parameters and to generate fundamental bedforms. In flume experiments, however, it is of critical importance that the flume be designed in a way that flocculated materials move under shear stress conditions that would be reasonable in natural environments. Although much flume work on muds has been conducted by hydraulic engineers, the transfer of that knowledge to sedimentology is hampered by the fact that engineers and sedimentologists are interested in different (though not mutually exclusive) products from such experiments. Engineers and hydrologists are commonly concerned with quantifying fluid flow properties, whereas sedimentogists are particularly interested in the sedimentary products that result from a variety of flow conditions. Recent sedimentologically oriented flume studies have shown that muds can form deposits at flow velocities and shear stresses that would suffice to transport and deposit medium grained sand. Mud suspensions are prone to flocculation and the resulting floccules travel in bedload and form ripples that accrete into beds. The latter finding suggests that many laminated shales were deposited from currents rather than by settling from slow moving or still water. There are many other sedimentary features in shales that can potentially be reproduced in flume studies and in

  16. Comparison of organic geochemistry and metal enrichment in two black shales: Cambrian Alum Shale of Sweden and Devonian Chattanooga Shale of United States

    USGS Publications Warehouse

    Leventhal, J.S.

    1991-01-01

    In most black shales, such as the Chattanooga Shale and related shales of the eastern interior United States, increased metal and metalloid contents are generally related to increased organic carbon content, decreased sedimentation rate, organic matter type, or position in the basin. In areas where the stratigraphic equivalents of the Chattanooga Shale are deeply buried and and the organic material is thermally mature, metal contents are essentially the same as in unheated areas and correlate with organic C or S contents. This paradigm does not hold for the Cambrian Alum Shale Formation of Sweden where increased metal content does not necessarily correlate with organic matter content nor is metal enrichment necessarily related to land derived humic material because this organic matter is all of marine source. In southcentral Sweden the elements U, Mo, V, Ni, Zn, Cd and Pb are all enriched relative to average black shales but only U and Mo correlate to organic matter content. Tectonically disturbed and metamorphosed allochthonous samples of Alum Shale on the Caledonian front in western Sweden have even higher amounts for some metals (V, Ni, Zn and Ba) relative to the autochthonous shales in this area and those in southern Sweden. ?? 1991 Springer-Verlag.

  17. Modifying shale oil to improve flow characteristics

    SciTech Connect

    Seitzer, W.H.; Lovell, P.F.

    1982-05-01

    Shale oil, which forms a viscous, wax slurry below 25 C, was treated in several different ways to try to improve its flow characteristics as measured in a concentric cylinder viscometer. Removing the wax does not greatly improve the pumpability of the oil. Hydrotreatment of the whole oil to take out nitrogen, sulfur, and oxygen can lower the viscosity by a factor of five or more, even though the pour point is not greatly affected. Apparently hydrogenolysis of the nitrogen, sulfur, and oxygen lowers the molecular weight of the oil without much modification of the paraffinic wax. The pour point of the shale oil can be decreased with various commercial pour improvers. Sometimes an accompanying drop in viscosity is observed, but most of this decrease is not stable to shear in the viscometer.

  18. Oil shale health and environmental risk analysis

    SciTech Connect

    Gratt, L.B.

    1983-04-01

    The potential human health and environmental risks of hypothetical one-million-barrels-per-day oil shale industry have been analyzed to serve as an aid in the formulation and management of a program of environmental research. The largest uncertainties for expected fatalities are in the public sector from air pollutants although the occupational sector is estimated to have 60% more expected fatalities than the public sector. Occupational safety and illness have been analyzed for the oil shale fuel cycle from extraction to delivery of products for end use. Pneumoconiosis from the dust environment is the worker disease resulting in the greatest number of fatalities, followed by chronic bronchitis, internal cancer, and skin cancers, respectively. Research recommendations are presented for reducing the uncertainties in the risks analyzed and to fill data gaps to estimate other risks.

  19. Environmental contamination due to shale gas development.

    PubMed

    Annevelink, M P J A; Meesters, J A J; Hendriks, A J

    2016-04-15

    Shale gas development potentially contaminates both air and water compartments. To assist in governmental decision-making on future explorations, we reviewed scattered information on activities, emissions and concentrations related to shale gas development. We compared concentrations from monitoring programmes to quality standards as a first indication of environmental risks. Emissions could not be estimated accurately because of incomparable and insufficient data. Air and water concentrations range widely. Poor wastewater treatment posed the highest risk with concentrations exceeding both Natural Background Values (NBVs) by a factor 1000-10,000 and Lowest Quality Standards (LQSs) by a factor 10-100. Concentrations of salts, metals, volatile organic compounds (VOCs) and hydrocarbons exceeded aquatic ecotoxicological water standards. Future research must focus on measuring aerial and aquatic emissions of toxic chemicals, generalisation of experimental setups and measurement technics and further human and ecological risk assessment.

  20. Energy trump for Morocco: the oil shales

    SciTech Connect

    Rosa, S.D.

    1981-10-01

    The mainstays of the economy in Morocco are still agriculture and phosphates; the latter represent 34% of world exports. Energy demand in 1985 will be probably 3 times that in 1975. Most of the oil, which covers 82% of its energy needs, must be imported. Other possible sources are the rich oil shale deposits and nuclear energy. Four nuclear plants with a total of 600 MW are projected, but shale oil still will play an important role. A contract for building a pilot plant has been met recently. The plant is to be located at Timahdit and cost $13 million, for which a loan from the World Bank has been requested. If successful in the pilot plant, the process will be used in full scale plants scheduled to produce 400,000 tons/yr of oil. Tosco also has a contract for a feasibility study.

  1. Geologic analysis of Devonian Shale cores

    SciTech Connect

    1982-02-01

    Cleveland Cliffs Iron Company was awarded a DOE contract in December 1977 for field retrieval and laboratory analysis of cores from the Devonian shales of the following eleven states: Michigan, Illinois, Indiana, Ohio, New York, Pennsylvania, West Virginia, Maryland, Kentucky, Tennessee and Virginia. The purpose of this project is to explore these areas to determine the amount of natural gas being produced from the Devonian shales. The physical properties testing of the rock specimens were performed under subcontract at Michigan Technological University (MTU). The study also included LANDSAT information, geochemical research, structural sedimentary and tectonic data. Following the introduction, and background of the project this report covers the following: field retrieval procedures; laboratory procedures; geologic analysis (by state); references and appendices. (ATT)

  2. Adsorption of xenon and krypton on shales

    NASA Technical Reports Server (NTRS)

    Podosek, F. A.; Bernatowicz, T. J.; Kramer, F. E.

    1981-01-01

    A method that uses a mass spectrometer as a manometer is employed in the measurement of Xe and Kr adsorption parameters on shales and related samples, where gas partial pressures were lower than 10 to the -11th atm, corresponding adsorption coverages are only small fractions of a monolayer, and Henry's Law behavior is expected and observed. Results show heats of adsorption in the 2-7 kcal/mol range, and Henry constants at 0-25 C of 1 cu cm STP/g per atmosphere are extrapolated. Although the adsorption properties obtained are variable by sample, the range obtained suggests that shales may be capable of an equilibrium adsorption with modern air high enough to account for a significant fraction of the atmospheric inventory of Xe, and perhaps even of Kr. This effect will nevertheless not account for the factor-of-25 defficiency of atmospheric Xe, in comparison with the planetary gas patterns observed in meteorites.

  3. Piceance Creek Basin, Colorado, Oil Shale Geodatabase

    USGS Publications Warehouse

    ,

    2006-01-01

    This geodatabase is a digital reproduction of three legacy USGS oil shale publications--MF-958 (Pitman and Johnson, 1978), MF-1069 (Pitman, 1979), and OC-132 (Pitman and others, 1990). The database consists of 106 feature classes in three feature datasets organized by publication. Each dataset contains isopach contours, isoresource contours, isoresource polygons, and corehole and drillhole locations with resource values for 12 kerogen-rich (R) and kerogen-lean (L) oil shale zones in the Piceance Creek Basin, Colorado. The uppermost zones, Mahogany and R-6, also contain detailed structure files. The zones in descending order are: Mahogany, R-6, L-5, R-5, L-4, R-4, L-3, R-3, L-2, R-2, L-1, and R-1.

  4. Development of Porosity Measurement Method in Shale Gas Reservoir Rock

    NASA Astrophysics Data System (ADS)

    Siswandani, Alita; Nurhandoko, BagusEndar B.

    2016-08-01

    The pore scales have impacts on transport mechanisms in shale gas reservoirs. In this research, digital helium porosity meter is used for porosity measurement by considering real condition. Accordingly it is necessary to obtain a good approximation for gas filled porosity. Shale has the typical effective porosity that is changing as a function of time. Effective porosity values for three different shale rocks are analyzed by this proposed measurement. We develop the new measurement method for characterizing porosity phenomena in shale gas as a time function by measuring porosity in a range of minutes using digital helium porosity meter. The porosity of shale rock measured in this experiment are free gas and adsorbed gas porosoty. The pressure change in time shows that porosity of shale contains at least two type porosities: macro scale porosity (fracture porosity) and fine scale porosity (nano scale porosity). We present the estimation of effective porosity values by considering Boyle-Gay Lussaac approximation and Van der Waals approximation.

  5. Oil shales of Europe, North Africa, and the Near East

    SciTech Connect

    Troger, U.

    1984-04-01

    Oil shale deposits are known from almost all countries in Europe and range in age from Paleozoic to Eocene. The geology of Europe is well known, and the discovery of new and significant oil shale deposits is not anticipated. A considerably different situation exists in North Africa and the Near East, where sparsely tested areas in the Sahara and desert fringe might contain important oil shale deposits. Most of the oil shale deposits in these areas (1) are of Cretaceous age, (2) occur with phosphate deposits, and (3) owe their origin to sedimentary processes associated with upwelling. Oil shales can be found from Turkey to Morocco along a paleocoastline, and better definition of this feature could result in new discoveries. In contrast to the US, oil shale deposits in Europe are being used as energy sources and will probably serve the same purpose in North Africa and the Near East.

  6. Plan for addressing issues relating to oil shale plant siting

    SciTech Connect

    Noridin, J. S.; Donovan, R.; Trudell, L.; Dean, J.; Blevins, A.; Harrington, L. W.; James, R.; Berdan, G.

    1987-09-01

    The Western Research Institute plan for addressing oil shale plant siting methodology calls for identifying the available resources such as oil shale, water, topography and transportation, and human resources. Restrictions on development are addressed: land ownership, land use, water rights, environment, socioeconomics, culture, health and safety, and other institutional restrictions. Descriptions of the technologies for development of oil shale resources are included. The impacts of oil shale development on the environment, socioeconomic structure, water availability, and other conditions are discussed. Finally, the Western Research Institute plan proposes to integrate these topics to develop a flow chart for oil shale plant siting. Western Research Institute has (1) identified relative topics for shale oil plant siting, (2) surveyed both published and unpublished information, and (3) identified data gaps and research needs. 910 refs., 3 figs., 30 tabs.

  7. Effect of different binders on the physico-chemical, textural, histological, and sensory qualities of retort pouched buffalo meat nuggets.

    PubMed

    Devadason, I Prince; Anjaneyulu, A S R; Babji, Y

    2010-01-01

    The functional properties of 4 binders, namely corn starch, wheat semolina, wheat flour, and tapioca starches, were evaluated to improve the quality of buffalo meat nuggets processed in retort pouches at F(0) 12.13. Incorporation of corn starch in buffalo meat nuggets produced more stable emulsion than other binders used. Product yield, drip loss, and pH did not vary significantly between the products with different binders. Shear force value was significantly higher for product with corn starch (0.42 +/- 0.0 Kg/cm(3)) followed by refined wheat flour (0.36 +/- 0.010 Kg/cm(3)), tapioca starch (0.32 +/- 0.010 Kg/cm(3)), and wheat semolina (0.32 +/- 0.010 Kg/cm(3)). Type of binder used had no significant effect on frying loss, moisture, and protein content of the product. However, fat content was higher in products with corn starch when compared to products with other binders. Texture profile indicated that products made with corn starch (22.17 +/- 2.55 N) and refined wheat flour (21.50 +/- 0.75 N) contributed firmer texture to the product. Corn starch contributed greater chewiness (83.8 +/- 12.51) to the products resulting in higher sensory scores for texture and overall acceptability. Products containing corn starch showed higher sensory scores for all attributes in comparison to products with other binders. Panelists preferred products containing different binders in the order of corn starch (7.23 +/- 0.09) > refined wheat flour (6.48 +/- 0.13) > tapioca starch (6.45 +/- 0.14) > wheat semolina (6.35 +/- 0.13) based on sensory scores. Histological studies indicated that products with corn starch showed dense protein matrix, uniform fat globules, and less number of vacuoles when compared to products made with other binders. The results indicated that corn flour is the better cereal binder for developing buffalo meat nuggets when compared to all other binders based on physico-chemical and sensory attributes. PMID:20492199

  8. Injection-induced Microseismicity in Colorado Shales

    NASA Astrophysics Data System (ADS)

    Talebi, S.; Boone, T. J.; Eastwood, J. E.

    Imperial Oil Resources Limited uses cyclic steam stimulation to recover oil from their Cold Lake oil field in Alberta. This operation, in particular situations, can be associated with the failure of well casings in the Colorado shales above the oil-bearing formation. A number of fluid injection operations was undertaken at this site and the associated microseismicity was detected using two three-component geophones and fifteen hydrophones. The purpose of this experiment was to simulate the occurrence of a casing failure, determine the feasibility of monitoring in a shallow environment, and characterize the microseismic activity. A calibration survey provided values of 1786 +/- 108 m/s for P-wave velocity, 643 +/- 56 m/s for S-wave velocity and 0.428 +/- 0.017 for Poisson's ratio in the shale formation. Estimates of the quality factor QP were 15 for the horizontal direction and 38 for the vertical direction, corroborating the evidence of velocity anisotropy. Calibration shots were located to within 10 m of the actual shot points using triangulation and polarization techniques. Several hundred microseis mic events were recorded and 135 events were located. The results showed that microseismic activity was confined to depths within 10 meters of the injection depth. The experiment clearly established the feasibility of detecting microseismicity induced by fluid injection rates typical of casing failures in shales at distances over 100 m.

  9. Map of assessed shale gas in the United States, 2012

    USGS Publications Warehouse

    ,; Biewick, Laura R. H.

    2013-01-01

    The U.S. Geological Survey has compiled a map of shale-gas assessments in the United States that were completed by 2012 as part of the National Assessment of Oil and Gas Project. Using a geology-based assessment methodology, the U.S. Geological Survey quantitatively estimated potential volumes of undiscovered gas within shale-gas assessment units. These shale-gas assessment units are mapped, and square-mile cells are shown to represent proprietary shale-gas wells. The square-mile cells include gas-producing wells from shale intervals. In some cases, shale-gas formations contain gas in deeper parts of a basin and oil at shallower depths (for example, the Woodford Shale and the Eagle Ford Shale). Because a discussion of shale oil is beyond the scope of this report, only shale-gas assessment units and cells are shown. The map can be printed as a hardcopy map or downloaded for interactive analysis in a Geographic Information System data package using the ArcGIS map document (file extension MXD) and published map file (file extension PMF). Also available is a publications access table with hyperlinks to current U.S. Geological Survey shale gas assessment publications and web pages. Assessment results and geologic reports are available as completed at the U.S. Geological Survey Energy Resources Program Web Site, http://energy.usgs.gov/OilGas/AssessmentsData/NationalOilGasAssessment.aspx. A historical perspective of shale gas activity in the United States is documented and presented in a video clip included as a PowerPoint slideshow.

  10. Tensile strengths of problem shales and clays. Master's thesis

    SciTech Connect

    Rechner, F.J.

    1990-01-01

    The greatest single expense faced by oil companies involved in the exploration for crude oil is that of drilling wells. The most abundant rock drilled is shale. Some of these shales cause wellbore stability problems during the drilling process. These can range from slow rate of penetration and high torque up to stuck pipe and hole abandonment. The mechanical integrity of the shale must be known when the shalers are subjected to drilling fluids to develop an effective drilling plan.

  11. Fugitive emissions from the Bakken shale illustrate role of shale production in global ethane shift

    NASA Astrophysics Data System (ADS)

    Kort, E. A.; Smith, M. L.; Murray, L. T.; Gvakharia, A.; Brandt, A. R.; Peischl, J.; Ryerson, T. B.; Sweeney, C.; Travis, K.

    2016-05-01

    Ethane is the second most abundant atmospheric hydrocarbon, exerts a strong influence on tropospheric ozone, and reduces the atmosphere's oxidative capacity. Global observations showed declining ethane abundances from 1984 to 2010, while a regional measurement indicated increasing levels since 2009, with the reason for this subject to speculation. The Bakken shale is an oil and gas-producing formation centered in North Dakota that experienced a rapid increase in production beginning in 2010. We use airborne data collected over the North Dakota portion of the Bakken shale in 2014 to calculate ethane emissions of 0.23 ± 0.07 (2σ) Tg/yr, equivalent to 1-3% of total global sources. Emissions of this magnitude impact air quality via concurrent increases in tropospheric ozone. This recently developed large ethane source from one location illustrates the key role of shale oil and gas production in rising global ethane levels.

  12. Shale gas characteristics of the Lower Toarcian Posidonia Shale in Germany: from basin to nanometre scale

    NASA Astrophysics Data System (ADS)

    Schulz, Hans-Martin; Bernard, Sylvain; Horsfield, Brian; Krüger, Martin; Littke, Ralf; di primio, Rolando

    2013-04-01

    The Early Toarcian Posidonia Shale is a proven hydrocarbon source rock which was deposited in a shallow epicontinental basin. In southern Germany, Tethyan warm-water influences from the south led to carbonate sedimentation, whereas cold-water influxes from the north controlled siliciclastic sedimentation in the northwestern parts of Germany and the Netherlands. Restricted sea-floor circulation and organic matter preservation are considered to be the consequence of an oceanic anoxic event. In contrast, non-marine conditions led to sedimentation of coarser grained sediments under progressively terrestrial conditions in northeastern Germany The present-day distribution of Posidonia Shale in northern Germany is restricted to the centres of rift basins that formed in the Late Jurassic (e.g., Lower Saxony Basin and Dogger Troughs like the West and East Holstein Troughs) as a result of erosion on the basin margins and bounding highs. The source rock characteristics are in part dependent on grain size as the Posidonia Shale in eastern Germany is referred to as a mixed to non-source rock facies. In the study area, the TOC content and the organic matter quality vary vertically and laterally, likely as a consequence of a rising sea level during the Toarcian. Here we present and compare data of whole Posidonia Shale sections, investigating these variations and highlighting the variability of Posidonia Shale depositional system. During all phases of burial, gas was generated in the Posidonia Shale. Low sedimentation rates led to diffusion of early diagenetically formed biogenic methane. Isochronously formed diagenetic carbonates tightened the matrix and increased brittleness. Thermogenic gas generation occurred in wide areas of Lower Saxony as well as in Schleswig Holstein. Biogenic methane gas can still be formed today in Posidonia Shale at shallow depth in areas which were covered by Pleistocene glaciers. Submicrometric interparticle pores predominate in immature samples. At

  13. Fugitive Emissions from the Bakken Shale Illustrate Role of Shale Production in Global Ethane Shift

    NASA Technical Reports Server (NTRS)

    Kort, E. A.; Smith, M. L.; Murray, L. T.; Gvakharia, A.; Brandt, A. R.; Peischl, J.; Ryerson, T. B.; Sweeney, C.; Travis, K.

    2016-01-01

    Ethane is the second most abundant atmospheric hydrocarbon, exerts a strong influence on tropospheric ozone, and reduces the atmosphere's oxidative capacity. Global observations showed declining ethane abundances from 1984 to 2010, while a regional measurement indicated increasing levels since 2009, with the reason for this subject to speculation. The Bakken shale is an oil and gas-producing formation centered in North Dakota that experienced a rapid increase in production beginning in 2010. We use airborne data collected over the North Dakota portion of the Bakken shale in 2014 to calculate ethane emissions of 0.23 +/- 0.07 (2 sigma) Tg/yr, equivalent to 1-3% of total global sources. Emissions of this magnitude impact air quality via concurrent increases in tropospheric ozone. This recently developed large ethane source from one location illustrates the key role of shale oil and gas production in rising global ethane levels.

  14. Eastern Devonian shales: Organic geochemical studies, past and present

    USGS Publications Warehouse

    Breger, I.A.; Hatcher, P.G.; Romankiw, L.A.; Miknis, F.P.

    1983-01-01

    The Eastern Devonian shales are represented by a sequence of sediments extending from New York state, south to the northern regions of Georgia and Alabama, and west into Ohio and to the Michigan and Ilinois Basins. Correlatives are known in Texas. The shale is regionally known by a number of names: Chattanooga, Dunkirk, Rhinestreet, Huron, Antrim, Ohio, Woodford, etc. These shales, other than those in Texas, have elicited much interest because they have been a source of unassociated natural gas. It is of particular interest, however, that most of these shales have no associated crude oil, in spite of the fact that they have some of the characteristics normally attributed to source beds. This paper addresses some of the organic geochemical aspects of the kerogen in these shales, in relation to their oil generating potential. Past organic geochemical studies on Eastern Devonian shales will be reviewed. Recent solid state 13C NMR studies on the nature of the organic matter in Eastern Devonian shales show that Eastern Devonian shales contain a larger fraction of aromatic carbon in their chemical composition. Thus, despite their high organic matter contents, their potential as a petroleum source rock is low, because the kerogen in these shales is of a "coaly" nature and hence more prone to producing natural gas.

  15. Characterization of asphalt additive produced from hydroretorted Alabama shale

    SciTech Connect

    Rue, D.M.; Roberts, M.J.

    1992-12-31

    Shale oil, produced from beneficiated Alabama shale by pressurized fluidized-bed hydroretorting, was fractionated to produce shale oil asphalt additives (SOA). Three shale oil fractions boiling above 305{degrees}C were added to standard AC-20 asphalt to improve pavement properties. The physical properties and aging characteristics of AC-20 asphalt binder (cement) containing SOA are similar to those of unmodified AC-20 asphalt binder. Asphalt pavement briquettes made with AC-20 asphalt binder containing 5 to 10 percent SOA have superior resistance to freeze-thaw cracking and a greater retention of tensile strength when wet compared to pavement briquettes containing AC-20 binder alone.

  16. Water Resources Management for Shale Energy Development

    NASA Astrophysics Data System (ADS)

    Yoxtheimer, D.

    2015-12-01

    The increase in the exploration and extraction of hydrocarbons, especially natural gas, from shale formations has been facilitated by advents in horizontal drilling and hydraulic fracturing technologies. Shale energy resources are very promising as an abundant energy source, though environmental challenges exist with their development, including potential adverse impacts to water quality. The well drilling and construction process itself has the potential to impact groundwater quality, however if proper protocols are followed and well integrity is established then impacts such as methane migration or drilling fluids releases can be minimized. Once a shale well has been drilled and hydraulically fractured, approximately 10-50% of the volume of injected fluids (flowback fluids) may flow out of the well initially with continued generation of fluids (produced fluids) throughout the well's productive life. Produced fluid TDS concentrations often exceed 200,000 mg/L, with elevated levels of strontium (Sr), bromide (Br), sodium (Na), calcium (Ca), barium (Ba), chloride (Cl), radionuclides originating from the shale formation as well as fracturing additives. Storing, managing and properly disposisng of these fluids is critical to ensure water resources are not impacted by unintended releases. The most recent data in Pennsylvania suggests an estimated 85% of the produced fluids were being recycled for hydraulic fracturing operations, while many other states reuse less than 50% of these fluids and rely moreso on underground injection wells for disposal. Over the last few years there has been a shift to reuse more produced fluids during well fracturing operations in shale plays around the U.S., which has a combination of economic, regulatory, environmental, and technological drivers. The reuse of water is cost-competitive with sourcing of fresh water and disposal of flowback, especially when considering the costs of advanced treatment to or disposal well injection and lessens

  17. Organoporosity Evaluation of Shale: A Case Study of the Lower Silurian Longmaxi Shale in Southeast Chongqing, China

    PubMed Central

    Chen, Fangwen; Lu, Shuangfang; Ding, Xue

    2014-01-01

    The organopores play an important role in determining total volume of hydrocarbons in shale gas reservoir. The Lower Silurian Longmaxi Shale in southeast Chongqing was selected as a case to confirm the contribution of organopores (microscale and nanoscale pores within organic matters in shale) formed by hydrocarbon generation to total volume of hydrocarbons in shale gas reservoir. Using the material balance principle combined with chemical kinetics methods, an evaluation model of organoporosity for shale gas reservoirs was established. The results indicate that there are four important model parameters to consider when evaluating organoporosity in shale: the original organic carbon (w(TOC0)), the original hydrogen index (IH0), the transformation ratio of generated hydrocarbon (F(Ro)), and the organopore correction coefficient (C). The organoporosity of the Lower Silurian Longmaxi Shale in the Py1 well is from 0.20 to 2.76%, and the average value is 1.25%. The organoporosity variation trends and the residual organic carbon of Longmaxi Shale are consistent in section. The residual organic carbon is indicative of the relative levels of organoporosity, while the samples are in the same shale reservoirs with similar buried depths. PMID:25184155

  18. Fossil fuel energy resources of Ethiopia: Oil shale deposits

    NASA Astrophysics Data System (ADS)

    Wolela, Ahmed

    2006-10-01

    The energy crisis affects all countries in the world. Considering the price scenarios, many countries in Africa have begun to explore various energy resources. Ethiopia is one of the countries that depend upon imported petroleum products. To overcome this problem, geological studies suggest a significant occurrence of oil shale deposits in Ethiopia. The Inter-Trappean oil shale-bearing sediments are widely distributed on the South-Western Plateau of Ethiopia in the Delbi-Moye, Lalo-Sapo, Sola, Gojeb-Chida and Yayu Basins. The oil shale-bearing sediments were deposited in fluviatile and lacustrine environments. The oil shales contain mixtures of algal, herbaceous and higher plant taxa. They are dominated by algal-derived liptinite with minor amounts of vitrinite and inertinite. The algal remains belong to Botryococcus and Pediastrum. Laboratory results confirm that the Ethiopian oil shales are dominated by long-chain aliphatic hydrocarbons and have a low sulphur content. Type-II and Type-I kerogen dominated the studied oil shales. Type-II and Type-I are good source rocks for oil and gas generation. Hydrogen index versus Tmax value plots indicated that most of the oil shale samples fall within the immature-early mature stage for hydrocarbon generation, consistent with the Ro values that range from 0.3% to 0.64%. Pyrolysis data of the oil shales sensu stricto indicate excellent source rocks with up to 61.2% TOC values. Calorific value ranges from 400 to 6165 cal/g. Palynological studies confirmed that the oil shale-bearing sediments of Ethiopia range from Eocene to Miocene in age. A total of about 253,000,000 ton of oil shale is registered in the country. Oil shale deposits in Ethiopia can be used for production of oil and gas.

  19. Influence of Bedding Angle on Borehole Stability: A Laboratory Investigation of Transverse Isotropic Oil Shale

    NASA Astrophysics Data System (ADS)

    Meier, T.; Rybacki, E.; Backers, T.; Dresen, G.

    2015-07-01

    The stability of wells drilled into bedded formations, e.g., shales, depends on the orientation between the bedding and the borehole axis. If the borehole is drilled sub-parallel to bedding, the risk of borehole instabilities increases significantly. In this study, we examined the formation of stress-induced borehole breakouts in Posidonia shale by performing a series of thick-walled hollow cylinder experiments with varying orientations of the bedding plane with respect to the borehole axis. The thick-walled hollow cylinders (40 mm in diameter and 80 mm in length containing an 8 mm diameter borehole) were loaded isostatically until formation of breakouts. The onset of borehole breakout development was determined by means of acoustic emission activity, strain measurements, ultrasonic velocities and amplitudes. The critical pressure for breakout initiation decreased from 151 MPa by approximately 65 % as the bedding plane inclination changed from normal to parallel to the borehole axis. The finely bedded structure in the shale resulted in an anisotropy in elasticity and strength from which the variation in strength dominated the integrity of the thick-walled hollow cylinders.

  20. Method and apparatus for processing oil shale in a rotary hearth

    SciTech Connect

    Merrill, L.S.

    1982-07-27

    Hydrocarbon containing oil shale is processed on the surface of a rabbled rotary hearth by mixing it with a heat exchange medium consisting of heated spent oil shale. Mixing is obtained by feeding the raw shale and the heated spent shale separately, but in proximity to one another, onto the surface of a hearth, and then subjecting both materials to rabbling action. This mixing causes heat from the heated spent shale heat exchange medium to be transferred to the fresh raw shale, which results in the removal of hydrocarbons from the raw shale. In one preferred embodiment, heated spent shale is obtained by removing spent shale from the hearth after processing, mixing it, preferably while it is still hot, with compatible combustible solids, and then introducing oxidizing gases into the mixture. This results in the burning of the combustible solids and any combustible materials remaining in the shale and the heating of the spent shale.

  1. Multivariate analysis relating oil shale geochemical properties to NMR relaxometry

    USGS Publications Warehouse

    Birdwell, Justin E.; Washburn, Kathryn E.

    2015-01-01

    Low-field nuclear magnetic resonance (NMR) relaxometry has been used to provide insight into shale composition by separating relaxation responses from the various hydrogen-bearing phases present in shales in a noninvasive way. Previous low-field NMR work using solid-echo methods provided qualitative information on organic constituents associated with raw and pyrolyzed oil shale samples, but uncertainty in the interpretation of longitudinal-transverse (T1–T2) relaxometry correlation results indicated further study was required. Qualitative confirmation of peaks attributed to kerogen in oil shale was achieved by comparing T1–T2 correlation measurements made on oil shale samples to measurements made on kerogen isolated from those shales. Quantitative relationships between T1–T2 correlation data and organic geochemical properties of raw and pyrolyzed oil shales were determined using partial least-squares regression (PLSR). Relaxometry results were also compared to infrared spectra, and the results not only provided further confidence in the organic matter peak interpretations but also confirmed attribution of T1–T2 peaks to clay hydroxyls. In addition, PLSR analysis was applied to correlate relaxometry data to trace element concentrations with good success. The results of this work show that NMR relaxometry measurements using the solid-echo approach produce T1–T2 peak distributions that correlate well with geochemical properties of raw and pyrolyzed oil shales.

  2. Updated methodology for nuclear magnetic resonance characterization of shales

    USGS Publications Warehouse

    Washburn, Kathryn E.; Birdwell, Justin E.

    2013-01-01

    Unconventional petroleum resources, particularly in shales, are expected to play an increasingly important role in the world’s energy portfolio in the coming years. Nuclear magnetic resonance (NMR), particularly at low-field, provides important information in the evaluation of shale resources. Most of the low-field NMR analyses performed on shale samples rely heavily on standard T1 and T2 measurements. We present a new approach using solid echoes in the measurement of T1 and T1–T2 correlations that addresses some of the challenges encountered when making NMR measurements on shale samples compared to conventional reservoir rocks. Combining these techniques with standard T1 and T2 measurements provides a more complete assessment of the hydrogen-bearing constituents (e.g., bitumen, kerogen, clay-bound water) in shale samples. These methods are applied to immature and pyrolyzed oil shale samples to examine the solid and highly viscous organic phases present during the petroleum generation process. The solid echo measurements produce additional signal in the oil shale samples compared to the standard methodologies, indicating the presence of components undergoing homonuclear dipolar coupling. The results presented here include the first low-field NMR measurements performed on kerogen as well as detailed NMR analysis of highly viscous thermally generated bitumen present in pyrolyzed oil shale.

  3. Market analysis of shale oil co-products. Appendices

    SciTech Connect

    Not Available

    1980-12-01

    Data are presented in these appendices on the marketing and economic potential for soda ash, aluminia, and nahcolite as by-products of shale oil production. Appendices 1 and 2 contain data on the estimated capital and operating cost of an oil shales/mineral co-products recovery facility. Appendix 3 contains the marketing research data.

  4. 18 CFR 270.306 - Devonian shale wells in Michigan.

    Code of Federal Regulations, 2011 CFR

    2011-04-01

    ... 18 Conservation of Power and Water Resources 1 2011-04-01 2011-04-01 false Devonian shale wells in... PROCEDURES Requirements for Filings With Jurisdictional Agencies § 270.306 Devonian shale wells in Michigan. A person seeking a determination that natural gas is being produced from the Devonian Age...

  5. 18 CFR 270.306 - Devonian shale wells in Michigan.

    Code of Federal Regulations, 2010 CFR

    2010-04-01

    ... 18 Conservation of Power and Water Resources 1 2010-04-01 2010-04-01 false Devonian shale wells in... PROCEDURES Requirements for Filings With Jurisdictional Agencies § 270.306 Devonian shale wells in Michigan. A person seeking a determination that natural gas is being produced from the Devonian Age...

  6. 78 FR 35601 - Oil Shale Management-General

    Federal Register 2010, 2011, 2012, 2013, 2014

    2013-06-13

    ... 78 FR 18547, is reopended. Send your comments so that they reach the BLM on or before July 15, 2013... March 27, 2013, the BLM published a proposed rule (78 FR 18547) to amend the BLM's commercial oil shale... Bureau of Land Management 43 CFR Parts 3900, 3920, and 3930 RIN 1004-AE28 Oil Shale...

  7. Implementation of an anisotropic mechanical model for shale in Geodyn

    SciTech Connect

    Attaia, A.; Vorobiev, O.; Walsh, S.

    2015-05-15

    The purpose of this report is to present the implementation of a shale model in the Geodyn code, based on published rock material models and properties that can help a petroleum engineer in his design of various strategies for oil/gas recovery from shale rock formation.

  8. Nuclear Waste Disposal: A Cautionary Tale for Shale Gas Development

    NASA Astrophysics Data System (ADS)

    Alley, William M.; Cherry, John A.; Parker, Beth L.; Ryan, M. Cathryn

    2014-07-01

    Nuclear energy and shale gas development each began with the promise of cheap, abundant energy and prospects for national energy independence. Nuclear energy was touted as "too cheap to meter," and shale gas promised jobs and other economic benefits during a recession.

  9. Analysis of eastern Devonian gas shales production data

    SciTech Connect

    Gatens, J.M.; Stanley, D.K.; Lancaster, D.E.; Lee, W.J.; Lane, H.S.; Watson, A.T.

    1989-05-01

    Production data from more than 800 Devonian shale wells have been analyzed. Permeability-thickness product and gas in place estimated from production data have been found to correlate with well performance. Empirical performance equations, production type curves, and an analytical dual-porosity model with automatic history-matching scheme were developed for the Devonian shale.

  10. Evaluation of Geochemical Fracture Conductivity Alterations in Shale under Laboratory Conditions

    NASA Astrophysics Data System (ADS)

    Radonjic, M.; Olabode, A.

    2015-12-01

    In large scale subsurface injection of carbondioxide as obtainable in carbon sequestration programs and in environmentally friendly hydraulic fracturing processes (using supercritical CO2), rock-fluid interaction can affect reservoir and seal rocks properties which are essential in monitoring the progress of these operations. The mineralogical components of sedimentary rocks are geochemically active particularly under enormous earth stresses. While geomechanical properties such as rock stiffness, Poisson's ratio and fracture geometry largely govern fluid flow characteristics in deep fractured formations, the effect of mineralization can lead to flow impedance in the presence of favorable geochemical and thermodynamic conditions. Experimental works which employed the use of analytical tools such as ICP-OES, XRD, SEM/EDS, TOC and BET techniques in investigating diagenetic and micro-structural properties of crushed shale caprock/CO2-brine system concluded that net precipitation reaction processes can affect the distribution of petrophysical nanopores in the shale as a result of rock-fluid interactions. Simulation results previously reported, suggest that influx-induced mineral dissolution/precipitation reactions within clay-based sedimentary rocks can continuously close micro-fracture networks, though injection pressure and effective-stress transformation first rapidly expand these fractures. This experimental modelling research investigated the impact of in-situ geochemical precipitation on conductivity of fractures under geomechanical stress conditions. Conductivity is measured as differential-pressure drop equivalence, using a pressure pulse-decay liquid permeametry/core flooding system, as geochemically saturated-fluid is transported through composite cores with embedded micro-tubings that mimic fractures. The reactive fluid is generated from crushed shale rocks of known mineralogical composition when flooded with aqueous CO2 at elevated temperature and pressure

  11. Hydrogeochemistry of the Antrim shale, Michigan Basin

    SciTech Connect

    Martini, A.M.; Richards, J.A.; Walter, L.M. . Dept. of Geology); Kaiser, C.J. )

    1992-01-01

    The upper Devonian Antrim shale represents an unconventional hydrocarbon reservoir for the Michigan Basin which produces both natural gas and water from fractures. This water exhibits extreme variations in salinity over a fairly small geographic area. Samples were collected from 36 wells and analyzed for various chemical and isotopic constituents. The most dilute end-member fluid possesses an carbonate alkalinity of 60 meq/kg and a chloride concentration of 22,000 mg/l. The most saline water has an alkalinity of 7 meq/kg and a chloride concentration of 141,000 mg/l. The source of salinity for the more concentrated Antrim waters is more problematic as the waters possess an unusual chemistry for the reservoir fluids of the Michigan Basin. The reservoir fluids are dominated by Ca-Na-Cl type brines, such as found in the Berea Formation (an upper Devonian sandstone) and the Traverse Group (a mid-Devonian carbonate) aquifers both of which are in stratigraphic proximity to the Antrim shale. The Antrim waters are Na-Cl dominated and cannot be explained by simple mixing of meteoric water with either of these brine aquifers. Large deficiencies in both Br and Ca relative to chloride within the Antrim waters precludes such a model. A likely source for the Na-Cl is from dissolution of Devonian age salt coupled with possible upward fluid migration through regional fractures. When a really mapped, most geochemical parameters exhibit variations consistent with northeast-southwest trends. This corresponds to the primary joint-orientations measured for the Antrim Formation. The hydrologic isolation demonstrated by fluid chemistry within the upper and mid-Devonian aquifers, coupled with the fracture recharge within the Antrim shale leads to a complex pattern of local fluid migration and water-rock interactions.

  12. Physical properties of Michigan Antrim Shale

    SciTech Connect

    Hockings, W.A.

    1980-08-01

    The physical properties of approximately 225 core samples and 700 samples of well cuttings from the Antrim Shale formation in the Michigan Basin were measured. The properties included density, porosity, permeability, pore size distribution, specific surface, and thermal expansion. Measurements were made before and after roasting in air and in nitrogen. In general the properties showed little variation with depth or location within the sampling area. The average porosity was about 8 percent of which approximately one-half consisted of closed pores. The porosity increased by about a factor of two after roasting at 500/sup 0/C. The permeability was found to be very low, averaging about 0.008 millidarcies. Permeability was higher in the direction parallel to the bedding planes than in the direction perpendicular to the planes. After roasting at 500/sup 0/C the permeability increased by about a factor of ten. Measurements while heating from 20 to 225/sup 0/C showed only minor variations in permeability with temperature. The specific surface area of the shale is low, averaging about 0.5 square meters per gram. The pore size distribution is bimodal with most of the pore volume in the size ranges of 0.01 to 0.1 and 10 to 100 micrometers. The shale expands about one percent perpendicular to bedding and 0.2 percent parallel to bedding when heated to 500/sup 0/C. The average expansion coefficient is 0.0025 percent per /sup 0/C on heating and 0.0010 on cooling. Peaks in the heating curve occur at about 25/sup 0/C and 450/sup 0/C.

  13. Shale gas wastewater management under uncertainty.

    PubMed

    Zhang, Xiaodong; Sun, Alexander Y; Duncan, Ian J

    2016-01-01

    This work presents an optimization framework for evaluating different wastewater treatment/disposal options for water management during hydraulic fracturing (HF) operations. This framework takes into account both cost-effectiveness and system uncertainty. HF has enabled rapid development of shale gas resources. However, wastewater management has been one of the most contentious and widely publicized issues in shale gas production. The flowback and produced water (known as FP water) generated by HF may pose a serious risk to the surrounding environment and public health because this wastewater usually contains many toxic chemicals and high levels of total dissolved solids (TDS). Various treatment/disposal options are available for FP water management, such as underground injection, hazardous wastewater treatment plants, and/or reuse. In order to cost-effectively plan FP water management practices, including allocating FP water to different options and planning treatment facility capacity expansion, an optimization model named UO-FPW is developed in this study. The UO-FPW model can handle the uncertain information expressed in the form of fuzzy membership functions and probability density functions in the modeling parameters. The UO-FPW model is applied to a representative hypothetical case study to demonstrate its applicability in practice. The modeling results reflect the tradeoffs between economic objective (i.e., minimizing total-system cost) and system reliability (i.e., risk of violating fuzzy and/or random constraints, and meeting FP water treatment/disposal requirements). Using the developed optimization model, decision makers can make and adjust appropriate FP water management strategies through refining the values of feasibility degrees for fuzzy constraints and the probability levels for random constraints if the solutions are not satisfactory. The optimization model can be easily integrated into decision support systems for shale oil/gas lifecycle

  14. Shale gas wastewater management under uncertainty.

    PubMed

    Zhang, Xiaodong; Sun, Alexander Y; Duncan, Ian J

    2016-01-01

    This work presents an optimization framework for evaluating different wastewater treatment/disposal options for water management during hydraulic fracturing (HF) operations. This framework takes into account both cost-effectiveness and system uncertainty. HF has enabled rapid development of shale gas resources. However, wastewater management has been one of the most contentious and widely publicized issues in shale gas production. The flowback and produced water (known as FP water) generated by HF may pose a serious risk to the surrounding environment and public health because this wastewater usually contains many toxic chemicals and high levels of total dissolved solids (TDS). Various treatment/disposal options are available for FP water management, such as underground injection, hazardous wastewater treatment plants, and/or reuse. In order to cost-effectively plan FP water management practices, including allocating FP water to different options and planning treatment facility capacity expansion, an optimization model named UO-FPW is developed in this study. The UO-FPW model can handle the uncertain information expressed in the form of fuzzy membership functions and probability density functions in the modeling parameters. The UO-FPW model is applied to a representative hypothetical case study to demonstrate its applicability in practice. The modeling results reflect the tradeoffs between economic objective (i.e., minimizing total-system cost) and system reliability (i.e., risk of violating fuzzy and/or random constraints, and meeting FP water treatment/disposal requirements). Using the developed optimization model, decision makers can make and adjust appropriate FP water management strategies through refining the values of feasibility degrees for fuzzy constraints and the probability levels for random constraints if the solutions are not satisfactory. The optimization model can be easily integrated into decision support systems for shale oil/gas lifecycle

  15. Measurements of Methane Emissions and Volatile Organic Compounds from Shale Gas Operations in the Marcellus Shale

    NASA Astrophysics Data System (ADS)

    Omara, M.; Subramanian, R.; Sullivan, M.; Robinson, A. L.; Presto, A. A.

    2014-12-01

    The Marcellus Shale is the most expansive shale gas reserve in play in the United States, representing an estimated 17 to 29 % of the total domestic shale gas reserves. The rapid and extensive development of this shale gas reserve in the past decade has stimulated significant interest and debate over the climate and environmental impacts associated with fugitive releases of methane and other pollutants, including volatile organic compounds. However, the nature and magnitude of these pollutant emissions remain poorly characterized. This study utilizes the tracer release technique to characterize total fugitive methane release rates from natural gas facilities in southwestern Pennsylvania and West Virginia that are at different stages of development, including well completion flowbacks and active production. Real-time downwind concentrations of methane and two tracer gases (acetylene and nitrous oxide) released onsite at known flow rates were measured using a quantum cascade tunable infrared laser differential absorption spectrometer (QC-TILDAS, Aerodyne, Billerica, MA) and a cavity ring down spectrometer (Model G2203, Picarro, Santa Clara, CA). Evacuated Silonite canisters were used to sample ambient air during downwind transects of methane and tracer plumes to assess volatile organic compounds (VOCs). A gas chromatograph with a flame ionization detector was used to quantify VOCs following the EPA Method TO-14A. A preliminary assessment of fugitive emissions from actively producing sites indicated that methane leak rates ranged from approximately 1.8 to 6.2 SCFM, possibly reflecting differences in facility age and installed emissions control technology. A detailed comparison of methane leak rates and VOCs emissions with recent published literature for other US shale gas plays will also be discussed.

  16. Black shale - its deposition and diagenesis.

    USGS Publications Warehouse

    Tourtelot, H.A.

    1979-01-01

    Depositional processes involve a range of relationships among such factors as organic productivity, clastic sedimentation rate, and the intensity of oxidation by which organic matter is destroyed. If enough organic material is present to exhaust the oxygen in the environment, black shale results. During diagenesis for a thickness of a few meters beneath the surface, sulfate is reduced and sulfide minerals may be deposited. Fermentation reactions in the next several hundred meters result in biogenic methane, followed successively at greater depths by decarboxylation reactions and thermal maturation that form additional hydrocarbons. -from Author

  17. Assessing the Adsorption Properties of Shales

    NASA Astrophysics Data System (ADS)

    Pini, R.

    2014-12-01

    Fine-grained rocks, such as shales, contain a significant amount of nanopores that can significantly contribute to their storage capacity through the mechanism of adsorption. The current ability to extract natural gas that is adsorbed in the rock's matrix is limited and current technology focuses primarily on the free gas in the fractures, thus leading to very low recovery efficiencies. Shales constitute also a great portion of so-called caprocks above potential CO2 sequestration sites; hereby, the adsorption process may limit the CO2 mobility within the cap-rock, thus minimizing leakage phenomena. Whether it is a reservoir or a caprock, understanding and quantifying the mechanisms of adsorption in these natural materials is key to improve the engineering design of subsurface operations. Results will be presented from a laboratory study that combines conventional techniques for the measurement of adsorption isotherms with novel methods that allows for the imaging of adsorption using x-rays. Various nanoporous materials are considered, thus including rocks, such as shales and coals, pure clay minerals and engineered adsorbents with well-defined nanopore structures, such as zeolites. Supercritical CO2 adsorption isotherms have been measured with a Rubotherm Magnetic Suspension balance by covering the pressure range 0.1-20~MPa. A medical x-ray CT scanner has been used to identify three-dimensional patterns of the adsorption properties of a packed-bed of adsorbent, thus enabling to assess the spatial variability of the adsorption isotherm. The data are analyzed by using thermodynamically rigorous measures of adsorption and a graphical method is applied for their interpretation. The density of the adsorbed phase is estimated and compared to data reported in the literature; the latter is key to disclose gas-reserves and/or potential storage capacity estimates. When evaluated against classic adsorbent materials, the adsorption mechanism in shales is further complicated by

  18. Assessment of industry needs for oil shale research and development

    SciTech Connect

    Hackworth, J.H.

    1987-05-01

    Thirty-one industry people were contacted to provide input on oil shale in three subject areas. The first area of discussion dealt with industry's view of the shape of the future oil shale industry; the technology, the costs, the participants, the resources used, etc. It assessed the types and scale of the technologies that will form the industry, and how the US resource will be used. The second subject examined oil shale R D needs and priorities and potential new areas of research. The third area of discussion sought industry comments on what they felt should be the role of the DOE (and in a larger sense the US government) in fostering activities that will lead to a future commercial US oil shale shale industry.

  19. Geology and resources of some world oil-shale deposits

    USGS Publications Warehouse

    Dyni, John R.

    2006-01-01

    Oil-shale deposits are in many parts of the world. They range in age from Cambrian to Tertiary and were formed in a variety of marine, continental, and lacustrine depositional environments. The largest known deposit is in the Green River Formation in the western United States; it contains an estimated 213 billion tons of in-situ shale oil (about 1.5 trillion U.S. barrels). Total resources of a selected group of oil shale deposits in 33 countries are estimated at 409 billion tons of in-situ shale oil, which is equivalent to 2.8 trillion U.S. barrels of shale oil. These amounts are very conservative because (1) several deposits mentioned herein have not been explored sufficiently to make accurate estimates, and (2) some deposits were not included in this survey.

  20. Isotope approach to assess hydrologic connections during Marcellus Shale drilling.

    PubMed

    Sharma, Shikha; Mulder, Michon L; Sack, Andrea; Schroeder, Karl; Hammack, Richard

    2014-01-01

    Water and gas samples were collected from (1) nine shallow groundwater aquifers overlying Marcellus Shale in north-central West Virginia before active shale gas drilling, (2) wells producing gas from Upper Devonian sands and Middle Devonian Marcellus Shale in southwestern Pennsylvania, (3) coal-mine water discharges in southwestern Pennsylvania, and (4) streams in southwestern Pennsylvania and north-central West Virginia. Our preliminary results demonstrate that the oxygen and hydrogen isotope composition of water, carbon isotope composition of dissolved inorganic carbon, and carbon and hydrogen isotope compositions of methane in Upper Devonian sands and Marcellus Shale are very different compared with shallow groundwater aquifers, coal-mine waters, and stream waters of the region. Therefore, spatiotemporal stable isotope monitoring of the different sources of water before, during, and after hydraulic fracturing can be used to identify migrations of fluids and gas from deep formations that are coincident with shale gas drilling. PMID:23772970