As we approach the four-month anniversary of www.heatingoil.com ‘s soft launch, we are pleased to introduce ourselves to the world in the form of a short video. As many of you have already discovered, HeatingOil.coms mission is to provide valuable heating oil information to heating oil consumers around the country. First, HeatingOil.com provides comprehensive coverage of all things heating oil. Our writers and editors scour every corner of the news universe to bring you the latest and most valuable information on heating oil prices, crude oil prices, heating oil equipment, home energy conservation, energy policy, and green energy technology. Second, HeatingOil.com provides heating oil consumers with quotes from the most reliable and trustworthy heating oil dealers in their area. Looking for better heating oil prices? Try HeatingOil.com. Want to know why oil prices are going up or down? Visit HeatingOil.com. Need to find out when to replace your oil-fired burner? Curious about what a US cap and trade system might cost you? Wellyou get the idea. Take a look at the video and tell us what you think! Thanks for visiting. Shot on a Canon 5dm2 running Magic Lantern, graded in Magic Bullet Looks. Music Kevin MacLeod Shot and Cut By: Nicholas Whitaker

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How to heat oil forauthentic Hungarian meatball stew; learn more about traditional Hungarian food in this free cooking video. Expert: Brandon Sarkis Bio: Brandon Sarkis has been a professional chef for more than 12 years, and he has worked in Austin, Texas, Columbus, Ohio, and Atlanta, Ga. Filmmaker: brandon sarkis

heating oil account
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www.compareheatingoilprices.org – heating oil suppliers and what you should know to save money this year.

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Home heating can get pretty expensive especially if you don’t know when is the right time to buy heating oil, where you should buy heating oil and how to find good heating oil deals. If you are a novice when it comes to buying heating oil, you may be spending more than you should in home heating oil.

With the recessionary economy that everyone is facing right now, the common question in most households is how to save on heating oil. Fair enough, home heating oil contributes largely on the household cost. So how do you actually save on home heating oil? Here are some tips:

Collect and select. If you think you are not able to save a lot on the present heating oil that you got, you should try to collect and select next time. Collect a number of heating oil deals and then compare them. Which one will give you the best benefits at the lowest cost? Select the best heating oil deal from your list.
Don’t wait until it is winter season before you fill up your heating oil tank.  As much as possible, have your tank re-filled early. You can get home heating oil at a cheap price if you buy it early. The price of heating oil climbs up during the winter season. This is due to the fact that the demand for it is very high. Furthermore, you can get a discount if you buy heating oil during the early season.
Always check the delivery. Make sure that you get what you pay for. Check the delivery docket against the actual content of your tank.
Bulk ordering always attract discount. What you can do is ask for a number of other people who would like to order heating oil as well. You can all do it together. Neighbors, friends, family – they can all be convinced to order heating oil with you. After all, all of you will get benefits from bulk ordering.
Loyalty to one heating oil supplier can also attract discount. If you are buying heating oil from just one heating oil supplier, you may get loyalty discount. You will also get extra privileges because the supplier values you as a customer.

These tips will help you save on home heating oil. You don’t have to spend a fortune to keep yourself and your family warm this winter season. Home heating can be affordable. You just have to be strategic and resourceful.

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H elin satirizei tin katastasi stin elliniki agora, enimeronei kai prostatevei ton katanaloti. Spiti kai thermansi. Exipno diafimistiko spot, gia tin paralavi petrelaiou thermansis. Your house and what do you really pay for heating oil? Greek funny commercial with a stand up comedy twist. The Greek petroleum market, heat, house, money, theft. Delivery.

History

Main article: History of the oil shale industry

A.C. Kirk’s retort, used in the mid-to-late 19th century, was one of the first vertical oil shale retorts.

A number of shale oil extraction technologies have evolved over a period of time. In the 10th century, a method of extracting oil from “some kind of bituminous shale” was described by the Arabian physician Masawaih al-Mardini (Mesue the Younger). The first shale oil extraction patent was granted by the British Crown in 1694 to three people who had “found a way to extract and make great quantities of pitch, tarr, and oyle out of a sort of stone”. Modern industrial extraction of shale oil originated in France with the implementation of a process invented by Alexander Selligue in 1838 and about a decade later in Scotland by implementation of the process invented by James Young. During the late 19th century, shale oil extraction plants were built in Australia, Brazil, Canada, and the United States. The 1894 invention of the Pumpherston retort (also known as the Bryson retort) marked the separation of oil shale industry from the coal industry.

China (Manchuria), Estonia, New Zealand, South Africa, Spain, Sweden, and Switzerland began extracting shale oil in the early 20th century. However, crude oil discoveries in Texas during the 1920s and in the Middle East during mid-century brought most oil shale industries to a halt. In 1944, the United States restarted shale oil extraction as part of its Synthetic Liquid Fuels Program. These industries continued until oil prices fell sharply in the 1980s. The last oil shale retort in the United States, operated by Unocal Corporation, closed in 1991. The United States’ oil-shale development program was restarted in 2003, followed by a commercial leasing program in 2005 permitting the extraction of oil shale and oil sands on federal lands in accordance with the Energy Policy Act of 2005.

As of 2009[update], shale oil extraction is in operation in Estonia, Brazil, and China. While, Australia, U.S. and Canada have tested shale oil extraction techniques with demonstration projects and are planning implementation on a commercial basis, Morocco and Jordan are also planning to start shale oil production. Only four technologies are in commercial use; namely Kiviter, Galoter, Fushun, and Petrosix.

Process principle

Overview of shale oil extraction

Shale oil extraction process decomposes oil shale and converts kerogen in oil shale into shale oil petroleum-like synthetic crude oil. The process is conducted by pyrolysis, hydrogenation, or thermal dissolution. The most common extraction method is pyrolysis (also known as retorting). In this process, oil shale is heated until its kerogen decomposes into vapors of a condensable shale oil and non-condensable combustible oil shale gas. Oil vapors and oil shale gas are collected and cooled, causing the shale oil to condense. In addition, oil shale processing produces spent shale, which is a solid residue. Spent shale may contain char (some authors use the terms coke residue or semi-coke instead of char) carbonaceous residue formed from kerogen. Depending on the exact composition of oil shale, other useful by-products are also generated during this process. These include ammonia, sulfur, aromatic compounds, pitch, asphalt, and waxes. The efficiency of extraction processes is often evaluated by comparing their yield to the results of a Fischer Assay performed on a sample of the shale.

Pyrolysis is an endothermic process that requires an external source of energy. Most technologies use other fossil fuels such as natural gas, oil, or coal to generate heat, but various experimental methods have used electricity, radio frequency, microwaves, or reactive fluids for this purpose. By-products of the retorting process such as oil shale gas and char may be burned as an additional source of energy and the heat contained in spent oil shale and oil shale ash may be reused to pre-heat the raw oil shale.

The temperature at which perceptible decomposition of oil shale occurs depends on the time-scale of the process. In ex situ retorting processes, it begins at 300 C (570 F) and proceeds more rapidly and completely at higher temperatures. The rate of decomposition is the highest when the temperature ranges between 480 C (900 F) and 520 C (970 F). The ratio of oil shale gas to shale oil generally increases along with retorting temperatures. For a modern in situ process, which might take several months of heating, decomposition may be conducted at temperatures as low as 250 C (480 F). Temperatures below 600 C (1,110 F) are preferable, preventing the decomposition of lime stone and dolomite in the rock and thereby limiting carbon dioxide emissions and energy consumption.

Hydrogenation and thermal dissolution (reactive fluid processes) extract the oil using hydrogen donors, solvents, or a combination of these. Thermal dissolution involves the application of solvents at elevated temperatures and pressures, increasing oil output by cracking the dissolved organic matter. Different methods produce shale oil with different properties.

Classifications

Industry analysts have created several classifications of the methods by which hydrocarbons are extracted from oil shale.

By process principles: Based on the treatment of raw oil shale by heat and solvents the methods are classified as pyrolysis, hydrogenation, or thermal dissolution.

By location: A frequently used distinction considers whether processing is done above or below ground, and classifies the technologies broadly as ex situ (displaced) or in situ (in place). In ex situ processing, also known as aboveround retorting, the oil shale is mined either underground or at the surface and then transported to a processing facility. In contrast, in situ processing converts the kerogen while it is still in the form of an oil shale deposit, following which it is then extracted via oil wells, where it rises in the same way as conventional crude oil.

By heating method: The heating methods used to decompose oil shale may be classified as direct or indirect. While methods that burn materials or insert heat carriers within the retort are classified as direct, methods that conduct heat through retort walls are described as indirect. As of 2009, most of the commercial retorts in operation or under development are direct heating retorts. Another classification is based upon whether the heat is delivered by solids (hot recycled solids methods) or gases. In principle, it is less expensive to deliver heat using solids, especially those already heated by the shale’s pyrolysis, as is the case when spent shale particles are used.

By retort style: Based on the materials and methods used to heat the oil shale to an appropriate temperature, its processing technologies have been classified into internal combustion, hot recycled solids, wall conduction, externallyenerated hot gas, reactive fluid, and volumetric heating methods. There are many possible realizations and combinations of these methods, which are summarized in the table shown below. Some processing technologies are difficult to classify due to their unique methods of heat input (e.g. ExxonMobil Electrofrac) or due to limited information.

Classification of processing technologies by heating method and location (according to Alan Burnham)

Heating Method

Above ground (ex situ)

Underground (in situ)

Internal combustion

Gas combustion, NTU, Kiviter, Fushun, Union A, Paraho Direct, Superior Direct

Occidental Petroleum MIS, LLNL RISE, Geokinetics Horizontal, Rio Blanco

Hot recycled solids

(inert or burned shale)

Alberta Taciuk, Galoter, Lurgi-Ruhrgas, TOSCO II, Chevron STB, LLNL HRS, Shell Spher, KENTORT II

-

Conduction through a wall

(various fuels)

Pumpherston, Hom Tov, Fischer Assay, Oil-Tech, EcoShale In-Capsule Process, Combustion Resources

Shell ICP (primary method), American Shale Oil CCR, IEP Geothermic Fuel Cell Process

Externally generated hot gas

PetroSIX, Union B, Paraho Indirect, Superior Indirect, Syntec process (Smith process)

Chevron CRUSH, Petro Probe, MWE IGE

Reactive fluids

IGT Hytort (high-pressure H2), donor solvent processes, Chattanooga fluidized bed reactor

Shell ICP (some embodiments)

Volumetric heating

-

IIT Research Institute, Lawrence Livermore National Laboratory, and Raytheon radiofrequency processes, Global Resource microwave process, Electro-Petroleum EEOP

By raw oil shale particles’ size: The various ex situ processing technologies may be differentiated by the size of the oil shale particles that are fed into the retorts. As a rule, oil shale “lumps” varying in diameter from 10 millimeters (0.4 in) to 100 millimeters (3.9 in) are used in internal hot gas carrier technologies, while oil shale that has been crushed into particulates less than 10 millimeters (0.4 in) in diameter are used in internal hot solid carrier technologies.

By complexity of technology: In situ technologies are usually classified either as true in situ processes or modified in situ processes. True in situ processes do not involve mining or crushing the oil shale. Modified in situ processes involve drilling and fracturing the target oil shale deposit to create voids for the improved flow of gases and fluids through the deposit, thereby increasing the volume and quality of the shale oil produced.

Ex situ technologies

Internal combustion

Internal combustion technologies burn materials (typically char and oil shale gas) within a vertical shaft retort to supply heat for pyrolysis. Typically raw oil shale is fed into the top of the retort and is heated by the rising hot gases, which pass through the descending oil shale, thereby causing decomposition. Shale oil vapors and evolving gases are then moved to a condensing system. Condensed shale oil is collected, while non-condensable gas is recycled and used to carry heat. In the lower part of the retort, spent oil shale is heated to about 900 C (1,650 F) to burn off the char. Recycled gas enters the bottom of the retort and cools the spent oil shale. The Union and Superior multimineral processes depart from this pattern. In the Union process, oil shale is fed through the bottom of the retort and a pump moves it upward. In the Superior multimineral process, oil shale is processed in a horizontal segmented doughnut-shaped traveling-grate retort.

These processes are thermally efficient, since much of the carbon within the shale is burnt, and can achieve 80-90% of Fischer assay yield. Two well-established shale oil industries use internal combustion technologies: Kiviter process facilities have been operated continuously in Estonia since the 1920s, and China’s Fushun Mining Group, a world leader in shale oil production, operates Fushun process facilities. Their product streams, however, are diluted by combustion exhaust.

Hot recycled solids

Hot recycled solids technologies deliver heat to the shale via solid particlesypically oil shale ash. These technologies usually employ rotating kiln retorts, fed by fine oil shale particles generally having a diameter of less than 10 millimeters (0.4 in); some technologies use particles even smaller than 2.5 millimeters (0.10 in). The particles are heated in a separate chamber or vessel, advantageously preventing the dilution of oil shale gas with combustion exhaust.

In the Galoter process, the spent oil shale is burnt in a separate furnace and the resulting hot ash is mixed with oil shale particles to cause decomposition. This process and its modified version, Enefit, have been used in Estonia’s Narva Oil Plant for several decades. The TOSCO II process uses hot shale ash and ceramic balls heated by contact with the ash. The distinguishing feature of the Alberta Taciuk process (ATP) is that the entire process occurs in a single rotating multihamber horizontal vessel. An ATP plant extracted 1.5 million barrels (238.4809410^3 m3) of shale oil between 2000 and 2005 at the Stuart Oil Shale Plant, but is now being dismantled.

Alberta Taciuk Processor retort

Conduction through a wall

These technologies transfer heat to the oil shale by conducting it through the retort wall. The shale feed usually consists of fine particles. Their advantage lies in the fact that retort vapors are not combined with combustion exhaust. The Combustion Resources process uses a hydrogenired rotating kiln, where hot gas is circulated through an outer annulus. The Oil-Tech staged electrically heated retort consists of individual inter-connected heating chambers, stacked atop each other. Its principal advantage lies in its modular design, which enhances its portability and adaptability. The Red Leaf Resources EcoShale In-Capsule Process combines surface mining with a lower-temperature heating method similar to in situ processes by operating within an earthen impoundment structure. Inside the impoundment, a hot gas circulated by parallel pipes heats the oil shale rubble. As the impoundment could be constructed in the empty space created by mining, it allows rapid reclamation of the topography.

Externally generated hot gas

In general, externally generated hot gas technologies are similar to internal combustion technologies in that they also process oil shale lumps in vertical shaft kilns. Significantly, though, the heat in these technologies is delivered by gases heated outside the retort vessel, and therefore the retort vapors are not diluted with combustion exhaust. The Petrosix process, used at the world’s largest operational surface oil shale pyrolysis retort in So Mateus do Sul, Paran, Brazil, employs this technology.

Reactive fluids

Reactive fluid technologies are suitable for processing oil shales with a low hydrogen content. In these technologies, hydrogen gas (H2) or hydrogen donors (chemicals that donate hydrogen during chemical reactions) react with coke precursors (chemical structures in the oil shale that are prone to form char during retorting but have not yet done so). The reaction roughly doubles the yield of oil, depending on the characteristics of oil shale and process technology.

Reactive fluids technologies include the IGT Hytort (high-pressure H2) process, donor solvent processes, and the Chattanooga fluidized bed reactor. In the IGT Hytort oil shale is processed in a high-pressure hydrogen environment. The Chattanooga process uses a fluidized bed reactor and an associated hydrogen-fired heater for oil shale thermal cracking and hydrogenation.

In situ technologies

In situ technologies heat oil shale underground by injecting hot fluids into the rock formation, or by using linear or planar heating sources followed by thermal conduction and convection to distribute heat through the target area. Shale oil is then recovered through vertical wells drilled into the formation. These technologies are potentially able to extract more shale oil from a given area of land than conventional ex situ processing technologies, as the wells can reach greater depths than surface mines. They present an opportunity to recover shale oil from low-grade deposits that traditional mining techniques could not extract.

During World War II a modified in situ extraction process was implemented without significant success in Germany. One of the earliest successful in situ processes was the underground gasification by electrical energy (Ljungstrm method) process exploited between 1940 and 1966 for shale oil extraction at Kvarntorp in Sweden. Prior to the 1980s, many variations of the in situ process were explored in the United States. The first modified in situ oil shale experiment in the United States was conducted by Occidental Petroleum in 1972 at Logan Wash, Colorado. The newest technologies explore a variety of heat sources and heat delivery systems.

Wall conduction

Shell’s freeze wall for in situ shale oil production was designed to separate the process from its surroundings

Wall conduction in situ technologies use heating elements or heating pipes placed within the oil shale formation. The Shell in situ conversion process (Shell ICP) uses electrical heating elements for heating the oil shale layer to between 650 F (340 C) and 700 F (370 C) over a period of approximately four years. The processing area is isolated from surrounding groundwater by a freeze wall consisting of wells filled with a circulating super-chilled fluid. Disadvantages of this process are large electrical power consumption, extensive water use, and the risk of groundwater pollution. The process, under development since the early 1980s, was tested at the Piceance Basin Mahogany Research Project. 1,700 barrels (270 m3) of oil were extracted in 2004 at a 30-by-40-foot (9.1 by 12 m) testing area.

American Shale Oil CCR Process

In the American Shale Oil CCR Process, superheated steam or another heat transfer medium is circulated through a series of pipes placed below the oil shale layer to be extracted. The system combines horizontal wells, through which steam is passed, and vertical wells, which provide both vertical heat transfer through refluxing of converted shale oil and a means to collect the produced hydrocarbons. Heat is supplied by combustion of natural gas or propane in the initial phase and by oil shale gas at a later stage.

The Independent Energy Partners’ Geothermic Fuels Cells Process (IEP GFC) extracts shale oil by exploiting a high-temperature stack of fuel cells. The cells, placed in the oil shale formation, are fueled by natural gas during a warm-up period and afterward by oil shale gas generated by its own waste heat.

Externally generated hot gas

Chevron CRUSH process

Externally generated hot gas in situ technologies use hot gases that are heated above-ground and then injected into the oil shale formation. The Chevron CRUSH process, developed in partnership with Los Alamos National Laboratory, injects heated carbon dioxide into the formation via drilled wells and heats the formation through a series of horizontal fractures in which the gas circulates. Petro Probe has proposed a process which involves injecting super-heated air into the oil shale formation. Mountain West Energy’s In Situ Vapor Extraction process uses similar principles of injection of high-temperature gas.

ExxonMobil Electrofrac

Main article: ExxonMobil Electrofrac

ExxonMobil’s in situ technology uses electrical heating with elements of both wall conduction and volumetric heating methods. It injects an electrically conductive material such as calcined petroleum coke into the hydraulic fractures created in the oil shale formation which then forms a heating element. Heating wells are placed in a parallel row with a second horizontal well intersecting them at their toe. This allows opposing electrical charges to be applied at either end.

Volumetric heating

Artist’s rendition of a radio wave-based extraction facility

The concept of oil shale volumetric heating by radio waves (radio frequency processing) was developed at the Illinois Institute of Technology during the late 1970s. This technology was further developed by Lawrence Livermore National Laboratory. The oil shale would be heated by vertical electrode arrays. Deeper volumes could be processed at slower heating rates by installations spaced at tens of meters. The concept presumes a radio frequency at which the skin depth is many tens of meters, thereby overcoming the thermal diffusion times needed for conductive heating. While the Laboratory has not conducted a rigorous evaluation of the concept, private investigations may have been undertaken. Its drawbacks include intensive electrical demand and the possibility that groundwater or char would absorb undue amounts of the energy.

Radio frequency processing in conjunction with critical fluids is being developed by Raytheon together with CF Technologies and tested by Schlumberger, while Global Resource Corporation is testing microwave heating. Electro-Petroleum proposes electrically enhanced oil recovery by the passage of direct current between cathodes in producing wells and anodes located either at the surface or at depth in other wells. The passage of the current through the oil shale formation results in resistive Joule heating. Microwave heating technologies are based on the same principles as radio wave heating, although it is believed that radio wave heating is an improvement over microwave heating because its energy can penetrate farther into the oil shale formation.

Economics

NYMEX light-sweet crude oil prices 19962009 (not adjusted for inflation)

Main article: Oil shale economics

The dominant question for shale oil production is under what conditions shale oil is economically viable. The various attempts to develop oil shale deposits have succeeded only when the shale-oil production cost in a given region is lower than the price of petroleum or its other substitutes. According to a survey conducted by the RAND Corporation, the cost of producing a barrel of shale oil at a hypothetical surface retorting complex in the United States (comprising a mine, retorting plant, upgrading plant, supporting utilities, and spent shale reclamation), would range between US95 (0600/m3), adjusted to 2005 values). Assuming a gradual increase in output after the start of commercial production, the analysis projects a gradual reduction in processing costs to 40 per barrel (0250/m3) after achieving the milestone of 1 billion barrels (16010^6 m3). Royal Dutch Shell has announced that its Shell ICP technology would realize a profit when crude oil prices are higher than  per barrel (0/m3), while some technologies at full-scale production assert profitability at oil prices even lower than  per barrel (0/m3).

To increase the efficiency of oil shale retorting and by this the viability of the shale oil production, researchers have proposed and tested several co-pyrolysis processes, in which other materials such as biomass, peat, waste bitumen, or rubber and plastic wastes are retorted along with the oil shale. Some modified technologies propose combining a fluidized bed retort with a circulated fluidized bed furnace for burning the by-products of pyrolysis (char and oil shale gas) and thereby improving oil yield, increasing throughput, and decreasing retorting time.

A critical measure of the viability of oil shale as an energy source lies in the ratio of the energy produced by the shale to the energy used in its mining and processing, a ratio known as “Energy Returned on Energy Invested” (EROEI). A 1984 study estimated the EROEI of the various known oil shale deposits as varying between 0.713.3; some companies and newer technologies assert an EROEI between 3 and 10. To increase the EROEI, several combined technologies were proposed. These include the usage of process waste heat, e.g. gasification or combustion of the residual carbon (char), and the usage of waste heat from other industrial processes, such as coal gasification and nuclear power generation. The water needed in some extraction processes offers an additional economic consideration: this may pose a problem in areas with water scarcity.

Environmental considerations

Main article: Environmental impact of the oil shale industry

Objections to its potential environmental impact have stalled governmental support for extraction of shale oil in some countries, e.g. Australia. Shale oil extraction may involve a number of different environmental impacts that vary with process technologies. Depending on the geological conditions and mining techniques, mining impacts may include acid drainage induced by the sudden rapid exposure and subsequent oxidation of formerly buried materials, the introduction of metals into surface water and groundwater, increased erosion, sulfur gas emissions, and air pollution caused by the production of particulates during processing, transport, and support activities. Surface mining for ex situ processing, as with in situ processing, requires extensive land use and ex situ thermal processing generates wastes that require disposal. Mining, processing, spent shale disposal, and waste treatment require land to be withdrawn from traditional uses and should therefore avoid areas of high population density. Depending on the processing technology, the waste material may contain pollutants including sulfates, heavy metals, and polycyclic aromatic hydrocarbons, some of which are toxic and carcinogenic. Experimental in situ conversion processes may reduce some of these impacts, but may instead cause other problems, such as groundwater pollution.

The production and usage of oil shale usually generates more greenhouse gas emissions, including carbon dioxide, than conventional fossil fuels. Depending on the technology and the oil shale composition, shale oil extraction may create also sulfur dioxide, hydrogen sulfide, carbonyl sulfide, and nitrogen oxides emissions. Developing carbon capture and storage technologies may reduce the processes’ carbon footprint.

Concerns have been prominently raised over the oil shale industry’s use of water, particularly in arid regions where water consumption is a sensitive issue. In some cases, oil shale mining requires the lowering of groundwater levels below the level of the oil shale strata, which may affect the surrounding arable land and forest. Above-ground retorting typically consumes between one and five barrels of water per barrel of produced shale oil, depending on technology. Water is usually used for spent shale cooling and oil shale ash disposal. In situ processing, according to one estimate, uses about one-tenth as much water.

A 2007 programmatic environmental impact statement issued by the United States Bureau of Land Management stated that surface mining and retort operations produce 2 to 10 US gallons (7.6 to 38 l; 1.7 to 8.3 imp gal) of waste water per 1 short ton (0.91 t) of processed oil shale.

See also

Oil shale geology

Oil shale reserves

References

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^ a b (PDF) Oil Shale. Colorado School of Mines. 2008. http://emfi.mines.edu/emfi2008/OilShale2008.pdf?CMSPAGE=outreach/cont_ed/emfi/emfi2008/OilShale2008.pdf. Retrieved 2008-12-24. 

^ Forbes, R.J. (1970). A Short History of the Art of Distillation from the Beginnings Up to the Death of Cellier Blumenthal. Brill Publishers. pp. 4142. ISBN 9789004006171. http://books.google.com/books?id=u_tui-7XXF0C&pg=PA41. Retrieved 2009-06-02. 

^ Moody, Richard (2007-04-20) (PDF). Oil & Gas Shales, Definitions & Distribution In Time & Space. In The History of On-Shore Hydrocarbon Use in the UK. Geological Society of London. p. 1. http://www.geolsoc.org.uk/webdav/site/GSL/shared/pdfs/specialist and regional groups/hogg_weymouth.pdf. Retrieved 2007-07-28. 

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^ a b c Dyni, John R. (2007). “Oil Shale”. in Clarke, A. W.; Trinnaman, J. A. (PDF). Survey of energy resources (21 ed.). World Energy Council. pp. 93115. ISBN 0946121265. http://www.worldenergy.org/documents/ser2007_final_online_version_1.pdf. Retrieved 2007-11-13. 

^ a b Prien, Charles H. (1976). “Survey of oil-shale research in last three decades”. in Teh Fu Yen; Chilingar, George V.. Oil Shale. Amsterdam: Elsevier. pp. 237243. ISBN 9780444414083. http://books.google.com/books?id=qkU7OcVkwaIC&pg=PA237. Retrieved 2009-06-05. 

^ a b c d Francu, Juraj; Harvie, Barbra; Laenen, Ben; Siirde, Andres; Veiderma, Mihkel (May 2007) (PDF). A study on the EU oil shale industry viewed in the light of the Estonian experience. A report by EASAC to the Committee on Industry, Research and Energy of the European Parliament. European Academies Science Advisory Council. pp. 1213; 1819; 2324; 28. http://www.easac.org/displaypagedoc.asp?id=78. Retrieved 2007-11-25. 

^ a b c d e f g h i j k l United States Office of Technology Assessment (June 1980) (PDF). An Assessment of Oil Shale Technologies. DIANE Publishing. pp. 108110; 133; 138139; 148150. NTIS order #PB80-210115. ISBN 9781428924635. http://www.princeton.edu/~ota/disk3/1980/8004/8004.PDF. Retrieved 2007-11-03. 

^ a b c d e f g h i j k l m n o p (PDF) Secure Fuels from Domestic Resources: The Continuing Evolution of America’s Oil Shale and Tar Sands Industries. United States Department of Energy, Office of Naval Petroleum and Oil Shale Reserves. 2007. pp. 3; 8; 1617; 2229; 3637; 4043; 5457. http://fossil.energy.gov/programs/reserves/npr/Secure_Fuels_from_Domestic_Resources_-_P.pdf. Retrieved 2007-07-11. 

^ a b c d e f g h i Johnson, Harry R.; Crawford, Peter M.; Bunger, James W. (2004) (PDF). Strategic significance of America’s oil shale resource. Volume II: Oil shale resources, technology and economics. Office of Deputy Assistant Secretary for Petroleum Reserves; Office of Naval Petroleum and Oil Shale Reserves; United States Department of Energy. pp. 1316; A2; B35. http://www.fossil.energy.gov/programs/reserves/npr/publications/npr_strategic_significancev2.pdf. Retrieved 2007-06-23. 

^ Bureau of Land Management (2005-09-20). “Nominations for Oil Shale Research Leases Demonstrate Significant Interest in Advancing Energy Technology”. Press release. http://www.blm.gov/wo/st/en/info/newsroom/2005/september/NR_050920.html. Retrieved 2007-07-10. 

^ Brendow, K. (2009). “Oil shale a local asset under global constraint” (PDF). Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) 26 (3): 357372. doi:10.3176/oil.2009.3.02. ISSN 0208-189X. http://www.kirj.ee/public/oilshale_pdf/2009/issue_3/oil-2009-3-357-372.pdf. Retrieved 2009-09-25. 

^ a b c d e f Qian, Jialin; Wang Jianqiu (2006-11-07). “World oil shale retorting technologies” (PDF). International Oil Shale Conference. Amman, Jordan: Jordanian Natural Resources Authority. http://www.sdnp.jo/International_Oil_Conference/rtos-A118.pdf. Retrieved 2007-06-29. 

^ a b Aarna, Indrek (2009). “Editor’s page. The 3rd International Oil Shale Symposium in Tallinn” (PDF). Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) 26 (3): 349356. doi:10.3176/oil.2009.3.01. ISSN 0208-189X. http://www.kirj.ee/public/oilshale_pdf/2009/issue_3/oil-2009-3-349-356.pdf. Retrieved 2009-09-25. 

^ Luck, Taylor (2008-08-07). “Jordan set to tap oil shale potential”. The Jordan Times (Jordan Press Foundation). http://www.jordantimes.com/index.php?news=9860. Retrieved 2008-10-25. 

^ “San Leon Energy Awarded Moroccan Oil Shale Exploration Project”. OilVoice (OilVoice). 2009-06-01. http://www.oilvoice.com/n/San_Leon_Energy_Awarded_Moroccan_Oil_Shale_Exploration_Project/05a3d3f1.aspx. Retrieved 2009-06-03. 

^ a b c d e Koel, Mihkel (1999). “Estonian oil shale”. Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) (Extra). ISSN 0208-189X. http://www.kirj.ee/public/oilshale/Est-OS.htm. Retrieved 2007-07-21. 

^ a b c Luik, Hans (2009-06-08). “Alternative technologies for oil shale liquefaction and upgrading” (PDF). International Oil Shale Symposium. Tallinn, Estonia: Tallinn University of Technology. http://www.oilshalesymposium.com/fileadmin/user_upload/documents/LUIK_2.pdf. Retrieved 2009-06-09. 

^ a b c d e f g h i j k l m n o Burnham, Alan K.; McConaghy, James R. (2006-10-16). “Comparison of the acceptability of various oil shale processes” (PDF). 26th Oil shale symposium. Golden, Colorado: Lawrence Livermore National Laboratory. pp. 2; 17. UCRL-CONF-226717. https://e-reports-ext.llnl.gov/pdf/341283.pdf. Retrieved 2007-05-27. 

^ a b The Engineering Societies Commission on Energy, Inc. (March 1981) (PDF). Synthetic Fuels Summary. Report No. FE-2468-82. United States Department of Energy. pp. 80; 8384; 90. http://www.fischer-tropsch.org/DOE/DOE_reports/10679_t10/10679_t10_sec05.pdf. Retrieved 2009-07-17. 

^ Gorlov, E.G. (October 2007). “Thermal Dissolution Of Solid Fossil Fuels” (PDF). Solid Fuel Chemistry (Allerton Press, Inc.) 41 (5): 290298. doi:0.3103/S0361521907050047. ISSN 1934-8029. http://www.springerlink.com/content/n06l546490wt3544/fulltext.pdf?page=1. Retrieved 2009-06-09. 

^ Koel, Mihkel; Ljovin, S.; Hollis, K.; Rubin, J. (2001). “Using neoteric solvents in oil shale studies” (PDF). Pure and Applied Chemistry (Blackwell Science) 73 (1): 153159. ISSN 0033-4545. http://old.iupac.org/publications/pac/2001/pdf/7301×0153.pdf. Retrieved 2010-01-22. 

^ Baldwin, R. M.; Bennett, D. P.; Briley, R. A. (1984). “Reactivity of oil shale towards solvent hydrogenation” (PDF). American Chemical Society. Division of Petroleum Chemistry (American Chemical Society) 29 (1): 148153. ISSN 0569-3799. http://www.osti.gov/energycitations/product.biblio.jsp?osti_id=6697587. Retrieved 2010-01-22. 

^ a b c Speight, James G. (2008). Synthetic Fuels Handbook: Properties, Process, and Performance. McGraw-Hill. pp. 182; 186. ISBN 9780071490238. http://books.google.com/books?id=E3pgqnGgHjIC&pg=PA182. Retrieved 2009-03-14. 

^ a b c d Smith, M.W.; Shadle, L.J.; Hill, D. (2007) (PDF). Oil Shale Development from the Perspective of NETL’s Unconventional Oil Resource Repository. United States Department of Energy. DOE/NETL-IR-2007-022. http://www.osti.gov/energycitations/servlets/purl/915351-0AdXs8/915351.pdf. Retrieved 2009-11-29. 

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^ a b c (PDF) Draft Oil Shale and Tar Sands Resource Management Plan Amendments to Address Land Use Allocations in Colorado, Utah, and Wyoming and Programmatic Environmental Impact Statement. Appendix A: Oil Shale Development Background and Technology Overview. Argonne National Laboratory. 2007-12-07. pp. 36; 5455. http://ostseis.anl.gov/documents/dpeis/vol3/OSTS_DPEIS_vol3_App_A.pdf. Retrieved 2008-05-11. 

^ Soone, Jri; Riisalu, Hella; Kekisheva, Ljudmilla; Doilov, Svjatoslav (2006-11-07). “Environmentally sustainable use of energy and chemical potential of oil shale” (PDF). International Oil Shale Conference. Amman, Jordan: Jordanian Natural Resources Authority. pp. 23. http://www.sdnp.jo/International_Oil_Conference/rtos-A104.pdf. Retrieved 2007-06-29. 

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^ Coates, Ralph L. (2007-10-16). “A New Improved Process for Processing Oil Shale Ore into Motor Ready Fuel Products” (PDF). 27th Oil Shale Symposium. Golden, Colorado: Colorado School of Mines. http://www.ceri-mines.org/documents/27symposium/presentations/av07-1hatfield.pdf. Retrieved 2009-04-12. 

^ Coates, Ralph L.; Hatfield, Kent E.; Smoot, L. Douglas (2007-10-17). “A method of reducing CO2 emissions from oil shale retorting” (PDF). 27th Oil Shale Symposium. Golden, Colorado: Colorado School of Mines. http://www.ceri-mines.org/documents/27symposium/presentations/av15-4coates.pdf. Retrieved 2009-04-12. 

^ Biglarbigi, Khosrow; Mohan, Hitesh; Crawford, Peter; Carolus, Marshall (2008-12-04). “Economics, Barriers, and Risks of Oil Shale Development in the United States” (PDF). 28th United States Association for Energy Economics/International Association for Energy Economics North America Conference. New Orleans: The United States Association for Energy Economics. http://www.usaee.org/usaee2008/submissions/OnlineProceedings/7995-Biglarbigi – Oil Shale Economics.pdf. Retrieved 2009-09-27. 

^ a b c Crawford, Peter M.; Biglarbigi, Khosrow; Killen, James R.; Dammer, Anton R.; Knaus, Emily (2008-09-22). “Advances in World Oil-Shale Production Technologies” (PDF). Society of Petroleum Engineers Annual Technical Conference and Exhibition. Denver: Society of Petroleum Engineers. http://www.usaee.org/usaee2008/submissions/OnlineProceedings/7995-Biglarbigi – Oil Shale Economics.pdf. Retrieved 2009-09-27. 

^ Laherrre, Jean H. (2005) (PDF). Review on oil shale data. Hubbert Peak. http://www.hubbertpeak.com/laherrere/OilShaleReview200509.pdf. Retrieved 2007-06-17. 

^ Rex, R.; Janka, J. C.; Knowlton, T. (1984). Cold Flow Model Testing of the Hytort Process Retort Design. 17th Oil Shale Symposium. Golden, Colorado: Colorado School of Mines Press. pp. 1736. 

^ Weil, S. A.; Feldkirchner, H. L.; Punwani, D. V.; Janka, J. C. (1979-01-01). IGT HYTORT Process for hydrogen retorting of Devonian oil shales. Chicago: Gas Technology Institute. CONF-790571-3. 

^ Kk, M. V.; Guner, G.; Suat Baci, A. (2008). “Application of EOR techniques for oil shale fields (in-situ combustion approach)” (PDF). Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) 25 (2): 217225. doi:10.3176/oil.2008.2.04. http://www.kirj.ee/public/oilshale_pdf/2008/issue_2/oil-2008-2-217-225.pdf. Retrieved 2008-06-07. 

^ a b Savage, Marshall T. (2006-10-17). “Geothermic fuel cells” (PDF). 26th Oil Shale Symposium. Golden, Colorado: Colorado School of Mines/. http://www.ceri-mines.org/documents/R05d-MarshallSavage.pdf. Retrieved 2009-09-25. 

^ a b Lee, Sunggyu; Speight, James G.; Loyalka, Sudarshan K. (2007). Handbook of Alternative Fuel Technologies. CRC Press. p. 290. ISBN 9780824740696. http://books.google.com/books?id=hyNbv60Px8oC&pg=PA290. Retrieved 2009-03-14. 

^ a b c d Bartis, James T.; LaTourrette, Tom; Dixon, Lloyd; Peterson, D.J.; Cecchine, Gary (2005) (PDF). Oil Shale Development in the United States. Prospects and Policy Issues. Prepared for the National Energy Technology Laboratory of the United States Department of Energy. The RAND Corporation. pp. x; 1518; 50. ISBN 978-0-8330-3848-7. http://www.rand.org/pubs/monographs/2005/RAND_MG414.pdf. Retrieved 2007-06-29. 

^ Jon Birger (2007-11-01). Oil shale may finally have its moment. Fortune. http://money.cnn.com/2007/10/30/magazines/fortune/Oil_from_stone.fortune/. Retrieved 2007-11-17. 

^ Spencer Reiss (2005-12-13). “Tapping the Rock Field”. WIRED magazine. http://www.wired.com/wired/archive/13.12/oilshale.html. Retrieved 2009-03-14. 

^ (PDF) Plan of Operation for Oil Shale Research, Development and Demonstration (R,D/D) Tract. E.G.L. Resources, Inc.. 2006-02-15. http://www.blm.gov/pgdata/etc/medialib/blm/co/field_offices/white_river_field/oil_shale.Par.62160.File.dat/PlanofOperation.pdf. Retrieved 2008-05-01. 

^ (PDF) Oil Shale Research, Development & Demonstration Project. Plan of Operation. Chevron USA, Inc.. 2006-02-15. http://www.blm.gov/pgdata/etc/medialib/blm/co/field_offices/white_river_field/oil_shale.Par.37256.File.dat/OILSHALEPLANOFOPERATIONS.pdf. Retrieved 2008-05-01. 

^ Shurtleff, Kevin; Doyle, Dave (March 2008). “Single well, single gas phase technique is key to unique method of extracting oil vapors from oil shale” (PDF). World Oil Magazine (Gulf Publishing Company). http://www.rmotc.doe.gov/Pdfs/WO.MWE.March08.pdf. Retrieved 2009-09-27. 

^ Plunkett, Jack W. (2008). Plunkett’s Energy Industry Almanac 2009: The Only Comprehensive Guide to the Energy & Utilities Industry. Plunkett Research, Ltd.. p. 71. ISBN 9781593921286. http://books.google.com/books?id=Ut3zgub_PRwC&pg=PT71. Retrieved 2009-03-14. 

^ a b Symington, William A.; Olgaard, David L.; Otten, Glenn A.; Phillips, Tom C.; Thomas,Michele M.; Yeakel, Jesse D. (2008-04-20). “ExxonMobil’s Electrofrac Process for In Situ Oil Shale Conversion” (PDF). AAAPG Annual Convention. San Antonio: American Association of Petroleum Geologists. http://www.nevtahoilsands.com/pdf/Oil-Shale-and-Tar-Sands-Company-Profiles.pdf. Retrieved 2009-04-12. 

^ a b Burnham, Alan K. (2003-08-20) (PDF). Slow Radio-Frequency Processing of Large Oil Shale Volumes to Produce Petroleum-like Shale Oil. Lawrence Livermore National Laboratory. UCRL-ID-155045. https://e-reports-ext.llnl.gov/pdf/243505.pdf. Retrieved 2007-06-28. 

^ Carlson, R. D.; Blase, E. F.; McLendon, T. R. (1981-04-22). “Development of the IIT Research Institute RF heating process for in situ oil shale/tar sand fuel extractionn overview”. Oil Shale Symposium Proceedings. 14th Oil Shale Symposium (Golden, Colorado: Colorado School of Mines): 138145. CONF-810456. 

^ (PDF) Radio Frequency/Critical Fluid Oil Extraction Technology. Raytheon. http://www.raytheon.com/businesses/rids/products/rtnwcm/groups/public/documents/content/rtn_bus_ids_prod_rfcf_pdf.pdf. Retrieved 2008-08-20. 

^ Moon, Ted (2008-02-01). “Oil-shale extraction technology has a new owner”. The Journal of Petroleum Technology (Society of Petroleum Engineers). http://www.spe.org/jpt/2008/02/oil-shale-extraction-technology-has-a-new-owner/. Retrieved 2008-08-20. 

^ Global Resource Corp. (2007-03-09). “Global Resource Reports Progress on Oil Shale Conversion Process”. Press release. http://www.downstreamtoday.com/news/article.aspx?a_id=1943. Retrieved 2008-05-31. 

^ Daniel, David Edwin; Lowe, Donald F.; Oubre, Carroll L.; Ward, Calvin Herbert (1999). Soil vapor extraction using radio frequency heating: resource manual and technology demonstration. CRC Press. p. 1. ISBN 9781566704649. http://books.google.com/books?hl=en&lr=&id=vd8EIXX-OOQC&oi=fnd&pg=PA1. Retrieved 2009-09-26. 

^ Schmidt, S. J. (2003). “New directions for shale oil:path to a secure new oil supply well into this century: on the example of Australia” (PDF). Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) 20 (3): 333346. ISSN 0208-189X. http://www.kirj.ee/public/oilshale/7_schmidt_2003_3s.pdf. Retrieved 2007-06-02. 

^ Tiikma, Laine; Johannes, Ille; Pryadka, Natalja (2002). “Co-pyrolysis of waste plastics with oil shale”. Proceedings. Symposium on Oil Shale 2002, Tallinn, Estonia: 76. 

^ Tiikma, Laine; Johannes, Ille; Luik, Hans (March 2006). “Fixation of chlorine evolved in pyrolysis of PVC waste by Estonian oil shales”. Journal of Analytical and Applied Pyrolysis 75 (2): 205210. doi:10.1016/j.jaap.2005.06.001. 

^ Veski, R.; Palu, V.; Kruusement, K. (2006). “Co-liquefaction of kukersite oil shale and pine wood in supercritical water” (PDF). Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) 23 (3): 236248. ISSN 0208-189X. http://www.kirj.ee/public/oilshale/oil-2006-3-4.pdf. Retrieved 2007-06-16. 

^ Aboulkas, A.; El Harfi, K.; El Bouadili, A.; Benchanaa, M.; Mokhlisse, A.; Outzourit, A. (2007). “Kinetics of co-pyrolysis of Tarfaya (Morocco) oil shale with high-density polyethylene” (PDF). Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) 24 (1): 1533. ISSN 0208-189X. http://www.kirj.ee/public/oilshale/oil-2006-3-4.pdf. Retrieved 2007-06-16. 

^ Ozdemir, M.; A. Akar, A. Aydoan, E. Kalafatoglu; E. Ekinci (2006-11-07). “Copyrolysis of Goynuk oil shale and thermoplastics” (PDF). International Oil Shale Conference. Amman, Jordan: Jordanian Natural Resources Authority. http://www.sdnp.jo/International_Oil_Conference/rtos-A114.pdf. Retrieved 2007-06-29. 

^ Siirde, Andres; Martins, Ants (2009-06-07). “Oil shale fluidized bed retorting technology with CFB furnace for buring the by-products” (PDF). International Oil Shale Symphosium. Tallinn, Estonia: Tallinn University of Technology. http://www.oilshalesymposium.com/fileadmin/user_upload/documents/SIIRDE.pdf. Retrieved 2009-05-22. 

^ Cleveland, Cutler J.; Costanza, Robert; Hall, Charles A. S.; Kaufmann, Robert (1984-08-31). “Energy and the U.S. Economy: A Biophysical Perspective” (PDF). Science (American Association for the Advancement of Science) 225 (4665): 890897. doi:10.1126/science.225.4665.890. PMID 17779848. http://www.eroei.com/pdf/Energy and the U.S. Economy- A Biophysical Perspective.pdf. Retrieved 2007-08-28. 

^ (PDF) Letter to the Senate Committee on Energy and Natural Resources. Oil Shale Alliance Inc.. 2006. http://www.petroprobe.com/articles/submissiontosenate.pdf. Retrieved 2009-02-12. 

^ Parkinson, Gerald (2007). “Oil Shale: The U.S. Takes Another Look at a Huge Domestic Resource”. Chemical Engineering Progress (American Institute of Chemical Engineers) 102 (7). http://findarticles.com/p/articles/mi_qa5350/is_200607/ai_n21394714. Retrieved 2008-08-21. 

^ Clark, Judy (2008-08-11). “Nuclear heat advances oil shale refining in situ”. Oil & Gas Journal (requires subscription) (PennWell Corporation) 106 (30): 2224. http://www.ogj.com/index/article-display/336580/s-articles/s-oil-gas-journal/s-volume-106/s-issue-30/s-general-interest/s-nuclear-heat-advances-oil-shale-refining-in-situ.html. Retrieved 2009-05-23. 

^ “Bligh bans Whitsundays shale oil mining”. ABC News (The Australian Broadcasting Corporation). 2008-08-24. http://www.abc.net.au/news/stories/2008/08/24/2344733.htm?section=justin. Retrieved 2009-09-19. 

^ “Environmental Impacts from Mining” (PDF). The Abandoned Mine Site Characterization and Cleanup Handbook. Office of Surface Mining. 2006-08-02. http://www.techtransfer.osmre.gov/NTTMainSite/Library/hbmanual/epa530c/chapter3.pdf. Retrieved 2008-03-29. 

^ a b (PDF) Driving It Home. Choosing the Right Path for Fueling North America’s Transportation Future. Natural Resources Defense Council. June 2007. http://www.nrdc.org/energy/drivingithome/drivingithome.pdf. Retrieved 2008-04-19. 

^ Mlder, Leevi (2004). “Estonian Oil Shale Retorting Industry at a Crossroads” (PDF). Oil Shale. A Scientific-Technical Journal (Estonian Academy Publishers) 21 (2): 9798. ISSN 0208-189X. http://www.kirj.ee/public/oilshale/1_ed_page_2004_2.pdf. Retrieved 2007-06-23. 

^ Tuvikene, Arvo; Sirpa Huuskonen, Kari Koponen, Ossi Ritola, lle Mauer, Pirjo Lindstrm-Sepp (1999). “Oil Shale Processing as a Source of Aquatic Pollution: Monitoring of the Biologic Effects in Caged and Feral Freshwater Fish” (PDF). Environmental Health Perspectives (National Institute of Environmental Health Sciences) 107 (9): 745752. doi:10.2307/3434660. http://www.ncbi.nlm.nih.gov/pmc/articles/PMC1566439/pdf/envhper00514-0093.pdf. Retrieved 2007-06-16. 

^ Argonne National Laboratory (1990). Environmental consequences of, and control processes for, energy technologies. William Andrew Inc. p. 104. ISBN 9780815512318. http://books.google.com/books?id=qgFtunVE5T8C&pg=PA104&lpg=PA104. Retrieved 2008-08-19. 

^ Bartis, Jim (2006-10-26). “Unconventional Liquid Fuels Overview” (PDF). World Oil Conference. Boston: Association for the Study of Peak Oil & Gas – USA. http://www.aspo-usa.com/fall2006/presentations/pdf/Bartis_J_Boston_2006.pdf. Retrieved 2007-06-28. 

^ Speckman, Stephen (2008-03-22). “Oil-shale ‘rush’ is sparking concern”. Deseret News (Deseret News Publishing Co.). ISSN 0745-4724. http://deseretnews.com/article/1,5143,695263708,00.html. Retrieved 2008-08-24. 

^ a b (PDF) Draft Oil Shale and Tar Sands Resource Management Plan Amendments to Address Land Use Allocations in Colorado, Utah, and Wyoming and Programmatic Environmental Impact Statement. Volume 2. Argonne National Laboratory. 2007-12-07. p. 43(36). http://ostseis.anl.gov/documents/dpeis/volumes/OSTS_DPEIS_Vol_2.pdf. Retrieved 2008-03-31. 

^ Fischer, Perry A. (August 2005). “Hopes for shale oil are revived”. World Oil Magazine (Gulf Publishing Company). Archived from the original on 2006-11-09. http://web.archive.org/web/20061109140826/http://worldoil.com/magazine/MAGAZINE_DETAIL.asp?ART_ID=2658&MONTH_YEAR=Aug-2005. Retrieved 2008-04-01. 

External links

Oil Shale. A Scientific-Technical Journal (ISSN 0208-189X)

Oil Shale and Tar Sands Programmatic Environmental Impact Statement (EIS) Information Center. Concerning potential leases of Federal oil sands lands in Utah and oil shale lands in Utah, Wyoming, and Colorado.

“Shale Oil Now” Campaign. Links and articles on America’s shale oil compiled by Jon Moseley

The United States National Oil Shale Association (NOSA)

Shale Oil Information Center. A Colorado non-profit corporation disseminating information focusing on the history of the extraction of oil shale and oil sands.

v  d  e

Petroleum industry

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Drilling engineering  Underbalanced drilling  Directional drilling  (Measurement while drilling  Geosteering)  Drilling fluid  Drill Stem Test

Development

Completion (Squeeze job)  Well logging  Pipeline transport  Tracers

Production

Artificial lift (Pumpjack  ESP  Gas lift)  EOR (Steam injection  Gas reinjection)  Water injection  Well intervention  Upstream  Midstream  Downstream  Refining

Technical challenges

Differential sticking  Drilling fluid invasion  Blowouts  Lost circulation

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Related articles

OPEC  History of petroleum  Peak oil  Oil price increases since 2003  Price of petroleum  Society of Petroleum Engineers

Categories: Oil shale technology | Petroleum production | Chemical engineeringHidden categories: Articles containing potentially dated statements from 2009 | All articles containing potentially dated statements

For the latest installment of the HeatingOil.com dealer profiles series, we bring you Medford Heating of Medford, New Jersey. Medfords second-generation president, Steven Foulk, spoke with HeatingOil.com about his companys full-fledged adoption of Bioheat (petroleum-based heating oil blended with biodiesel) as its product. Foulk explains the many benefits of Bioheat that led his company to make the switch to the green fuel: high-efficiency burning in oilheat systems, lower emissions, domestic production that reduces our countrys dependence on foreign oil, and reliance on a feed stock (soybeans) that does not detract from food supplies. As Foulk puts it, the industrys been full of change. With a president who has repeatedly pledged to support increased production of biofuels like biodiesel and several state governments considering laws requiring biodiesel blending into heating oil, the industrys future looks green. Building on a 50-year history of responsibility and forward thinking, Medford Heating has already brought that future to southern New Jersey. Watch the video profile of Medford Heating below or on HeatingOil.coms YouTube channel.
Video Rating: 5 / 5

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This little treatise was prompted, in the beginning, by recurrent published stories having to do with the airlines’ difficulties in coping with extraordinarily high, and “volatile,” jet fuel costs.  Even so, it applies with equal force to users of Heating Oil and Diesel fuel, which of course also are refined products derived from Crude Oil, and which are somewhat similar to jet fuel, which itself is most akin to kerosene.  User groups other than airlines would include railroads, trucking companies, garbage collection companies whether public or private, school districts which operate school bus fleets, taxicab fleets, bus lines, courier services which operate airplane fleets, Governments, shipowners and cruise lines, hotel and motel companies, and owners or operators of office buildings, industrial buildings, and apartment buildings.  For the moment, however, let’s focus on the airlines, about which most has been written and spoken, by themselves and by others.

Historically, the airlines’ greatest single cost has been the cost of labor.  However, in recent years – especially during the great price advance of jet fuel in 2007 and 2008 – the equation was turned on its head, whereby the cost of fuel became the single largest line item of operating cost.  That still holds true, we are told, in spite of the massive decline in fuel prices following their peak in the summer of 2008.

Some airlines were (relatively) prepared for the price spike in 2008 by virtue of certain hedging programs, which had the effect of reducing their net cost of fuel.  Others had no hedging programs at all, and were left exposed when prices surged.

Some airlines have fuel price-hedging programs in place right now.  One wonders whether they are purely defensive, or whether an effort is being made to positively realize trading gains.  One large airline has announced a fuel hedge loss of close to 0 million for the latest quarter.  Do we rightly read that to mean that the actual cost of fuel was in addition to the hedging loss?  If the program is entirely defensive, it isn’t working very well; and if it contains elements of an offensive-type strategy, it isn’t working very well, either.

It occurs to me that, in order for a fuel hedging strategy to be truly successful, it must be geared not only to a strategy of defense against catastrophic fuel price increases, but also to a strategy to make a profit on fuel trading.  A basketball game cannot be won by playing defense only; you actually do need to put the ball in the basket at the other end of the floor once in a while.  It also occurs to me that it is necessary to understand our probable location within the wave cycle at any given time, which in turn requires a knowledge of the wave principle in the first place.

The whole aspect of an airline’s fuel hedging department has to change from that of a necessary evil which consumes dollars in a purely defensive effort to that of a profit center.

The profit center’s stated target, its Mission, would be a net fuel cost of Zero.

It is not reasonable to expect that a target of Zero would be attainable.  Such a result, while theoretically possible, might well require an allocation of funds wildly beyond the realm of possibility.  Even so, and even if the investment were to be scaled down to a realistic level, the principle is still valid.  The profit center would be graded on measurable results  monthly, quarterly, semi-annually, and annually, based on several criteria, among which might be (1) Return on Investment and (2) Attained Percentage of the Target for the Period, the target being Zero.  For example, if the fuel bill for the month were ,000,000 and trading profits (in Heating Oil, for example) for the month were ,000,000, the Attained Percentage of the Target for the Period would be .10.  It might be that an Attained Percentage of .10 would be considered to be a good result.  It might also be that an Attained Percentage of .010 would be considered to be a good grade.  The important points are that there would be a target at which to aim, month by month by month, and that the results would be measurable and subject to comparison, period by period.

Of course, such an approach would likely entail turning an airline’s present fuel hedging approach upside down and inside out.  It would necessitate a reversal of the thought process.  Some people could do it; some could not.  It might well require the importation of different trading skills.  The transition might be difficult.  It would require the total commitment of Management.

I hear the sound of applecarts being upset.  But before the word “can’t” comes to the fore, perhaps we could find a voice or two who say “maybe.”

Respectfully submitted.

William Kurtz

July 30, 2009