Agricultural Transportation and Energy Issues. Senate hearing 2005.

Preface. What follows are excerpts from this hearing.  Over and over senators warn of our dependence on oil.  The question is: what are they doing about it?  I’d guess given the crackdown on immigration that the government is aware of limits to growth, though since 1 million legal immigrants are admitted a year, perhaps not…  What’s scary to me is that the military and homeland security are certainly planning for social unrest when energy grows scarce, and probably the military has dibs on the Strategic Petroleum Reserve when times get tough.  But those plans are being kept hidden from the public.

Alice Friedemann    www.energyskeptic.com   author of 2021 Life After Fossil Fuels: A Reality Check on Alternative Energy best price here; 2015 When Trucks Stop Running: Energy and the Future of Transportation”, Barriers to Making Algal Biofuels, & “Crunch! Whole Grain Artisan Chips and Crackers”. Podcasts: Crazy Town, Collapse Chronicles, Resistance Radio, Derrick Jensen, Practical Prepping, KunstlerCast 253, KunstlerCast278, Peak Prosperity, XX2 report

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Senate 109–510. November 9, 2005. Agricultural Transportation and Energy Issues. U.S. Senate. 123 pages. 

SENATOR NORM COLEMAN, MINNESOTA

Our transportation system is the lifeblood of agriculture.

U.S. agriculture is highly dependent upon the effectiveness of our integrated agriculture transportation system, and poor transportation directly adds to farmers’ bottom lines. Truck, rail, and river must be able to work together to compete with each other and keep the price of transportation down.

The transportation and energy challenges we face this year hit our farmers particularly hard.  Both transportation and energy are basic inputs into almost every farm and business, so high transportation and energy costs go to the heart of our competitiveness as a nation.

Congress recently passed a Highway Bill to address many of our surface transportation needs, but we have yet to pass the Water Resources Development Act, known as ‘‘WRDA,’’ to authorize crucial funding for our water infrastructure. Improving our river navigation will not only lower the cost of doing business for producers, but also mean less highway congestion

Hurricane Katrina certainly highlighted the importance of river transportation to farmers, which was devastating to the agriculture transportation system in and around the Mississippi Gulf region. Overall, this area is responsible for about 60 to 70% of U.S. world grain exports.

It is estimated that one in four acres of U.S. production is destined for export channels; 60% of which goes through New Orleans to the Gulf.

Rail and truck transport have been critical for agriculture in this time of interrupted river traffic; but clearly, agriculture is heavily dependent on our rivers. And we cannot expect to compete with the rest of the world using locks over 70 years old, as we have on the Upper Mississippi River system.

But all of us here know transportation costs can’t be just boiled down to infrastructure. The price paid for energy has an enormous impact. And beyond transportation, energy prices are taking a severe toll on our farmers.

On average, energy accounts for about 13% of a farmer’s expenses. The increased costs of fertilizer caused by high natural gas prices, combined with extraordinarily high diesel prices and high transportation costs, have been a true challenge for producers today, who can’t raise their prices and are forced to absorb these very severe increases.

Clearly, our energy problems go far beyond Hurricane Katrina. I want to share  a few numbers with you: 37, 53, 60, 74. These four numbers represent the percentage of petroleum supplies we purchased overseas in 1980, 2002, today, and the projected purchases we will make in 2025: from 37 to 74. We were addicted to foreign oil in 1980; wherein our costs double our dosage down the road.

I am serious when I say that this Nation’s energy dependence is the greatest threat to our economy, our security, and our freedom that this Nation faces.

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Fletcher R. Hall, Executive Director. The agricultural and food transporters conference of the American Trucking Associations.

According to U.S. government estimates, the transportation of agricultural commodities and products accounts for a significant portion of all U.S. freight traffic. In fact, defining agricultural movement to include movements of farm inputs, raw agricultural commodities, and processed agricultural commodities, agriculture is a primary user of transportation services in the U.S. at over 23% of total tonnage and over 31% of the total ton-miles, moved every year.

The U.S. agricultural sector depends extensively upon truck transportation for a number of reasons. Agricultural production typically occurs in areas substantially removed from the final markets of agricultural products.  Production and processing are generally dispersed over wide areas or regions. Agricultural commodities and products also tend to require a wide range of transportation services which are significantly impacted by energy issues and energy prices.  Agricultural commodities and products such as grains, are bulky and of low value. Others, such as fresh fruits and vegetables, and meats are highly perishable and of high value. Still others, such as livestock, require specialized handling and equipment. Modern commercial agriculture is also input-intensive, using a broad range of products from fertilizers to feed additives. These inputs generate demands for truck transportation, and their costs are affected by the price and availability of various forms of energy.

The trucking industry is essential to agriculture as trucks are now the primary transport mode for the movement of all major agricultural commodities.

  • Trucks are the leading transport mode for the movement of fresh fruits and vegetables in the U.S., with a market share of over 90%
  • 95% of livestock transportation is handled by truck, and fresh dairy products are primarily handled by trucks as well
  • According to the USDA’s latest grain transportation modal share analysis (October 2004), trucks transported 68.4% of all domestic grain movements ni the U.S. during the year 2000. Rail and barge shares decreased, while truck shares increased through 2000,making trucks the dominant mode for grain transport.
  • Trucks are the largest carrier of produce to ocean ports for export

Rising fuel costs have the potential to create a ripple effect through the economy whereby consumers are likely to see higher costs for whatever they are purchasing whether grown on a farm or delivered by truck. This is significant because 80% of communities in the U.S. get their goods solely by truck.

Higher diesel prices will raise the cost of harvesting and post-harvesting treatment e.g., drying, moving and storing of crops in and from the field. Higher energy costs in agricultural transportation will cause food prices to rise, as much as 3.5% this year (versus 2.5% per year in the preceding decade).

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SENATOR KEN SALAZAR, COLORADO.    Here is what I am hearing from my state during harvest. Agriculture producers are some of the largest fuel consumers in the U.S., and producers are facing enormous fuel costs. For example, in Grand Junction, Colorado, diesel prices today are still over $3 a gallon. I have heard from a farmer in Brandon, Colorado, who has a dry land wheat farm of about 5,000 acres. He has seen a 217% increase in diesel costs, and about a 71% increase in gasoline costs since the summer of 2004. This operation will use about 200 to 250 gallons of diesel per day during the heavy farming season. If fuel prices do not moderate, this farmer will realize a doubling of fuel costs for 2006; equating to an additional $16,000 annually, just for his fuel expenses on his farm. I heard from another farmer in northeastern Colorado who, in order to cover the increasing price of fuel, has applied for additional loans from his local bank; only to be turned down because he was already over-extended on his existing loans. These anecdotes illustrate a problem which goes far beyond the borders of Colorado. After 5 years of weather-related disasters, such as droughts, hurricanes, or fires, these higher-input costs are having a severe impact not only on producers’ ability to harvest this year, but also in their ability to secure financing to operate for the next year. This is a crisis that is undermining the stability of farming operations across our country. This is a crisis and emergency that we must address.

I believe they need economic loss assistance, which will help offset the staggering increases in fuel and fertilizer costs.  Our producers are in a downward spiral, and we must help end that downward spiral. Each day, this energy crisis continues to drive farmers and ranchers into deeper debt, putting the life of our rural communities at risk.

SENATOR BLANCHE LINCOLN, ARKANSAS. The severe drought conditions which the country has seen, particularly in our region, combined with the high fuel costs, have forced our farmers to experience extremely high operating costs. We are hearing from our bankers, as well, our financial institutions. I have got three counties of banks that are telling me that they are going to have a record number of farm operations that will not be able to pay out or cash-flow because of the record amounts of resource they have had to put into producing a crop, and then to find the natural disasters that have wreaked havoc on them at harvest time. So it is a time when we have to remember what it is our producers do. And they do it very quietly. Very quietly, they produce the safest, most abundant and affordable food supply in the world. They make sure that, per capita, we pay less for our food supply than any other developed nation in the world. Our farmers are devastated, in terms of these fuel costs. And it is not just in terms of the diesel they put in their tractors. It is also the feedstock for their fertilizer. They are paying record prices for fertilizer, the feedstock, in the natural gas that is causing that to happen. And the projection is that in the next several years, we will no longer have a domestic production of fertilizer. So once again, we are going to set another variable onto our producers of not knowing what and when they can depend on the products that they need in order to produce this safe and abundant food supply.

Those small, rural county roads oftentimes are not able to transport the large cotton modules and the other crops that we grow. So we have got a lot of different issues there. But without a doubt, the fuel costs are the greatest burden that our farmers are carrying right now.

I would like to also echo Senator Salazar, in terms of relieving our dependence on foreign oil.

One consistent thing I hear from our ag producers in the South, it is, ‘‘Please, please, allow us to be a part of providing the kind of fuels, the renewable fuels, that we need in this country, to lessen our dependence on foreign oil and give us yet one more secondary market where we can market our products and our crops.’’

SENATOR DEBBIE STABENOW, MICHIGAN.   one of the reasons I was a strong supporter of the energy provision of the 2002 Farm Bill was because of the important ways in which we in agriculture can help to solve the problem of our dependence, over-dependence, on foreign oil.

KEITH COLLINS, PH. D., CHIEF ECONOMIST, U.S. DEPARTMENT OF AGRICULTURE.  The hurricanes also worsened the already tight energy situation. Farmers paid 43% more for diesel fuel in October 2005 than a year earlier; while prices paid for fertilizer by farmers were up 13% this October, compared with last October.

HOWARD GRUENSPECHT, DEPUTY ADMINISTRATOR, ENERGY INFORMATION ADMINISTRATION, U.S.

Hurricanes Katrina and Rita wrought incredible devastation on the central Gulf Coast; most importantly, in terms of human suffering, but also in energy impacts that have spread well beyond the stricken area. At its peak impact, Katrina shut down over 25 % of U.S. crude oil production, 20 % of our crude imports, 10 % of our domestic refining, and over 15 % of U.S. natural gas production. Rita compounded those impacts. For example, nearly 30 percent of total U.S. refining was shut in ahead of Rita, and outages continued at nearly 20 percent of refining capacity for some weeks thereafter.

The farm sector, as many of you have mentioned in your opening statements, is a significant consumer of energy, particularly diesel fuel, propane, and electricity. In addition to direct farm use of energy, agriculture is indirectly affected by energy requirements in the fertilizer industry, specifically in nitrogenous fertilizers.

Even before Hurricane Katrina struck, crude oil and petroleum prices were setting records. Oil prices worldwide have been rising steadily since 2002, due in large part to growth in global demand which has used up much of the world’s surplus production capacity. Refineries have been running at increasingly high levels of utilization in many parts of the world, including the United States.

Using previous information about energy use on farms and in closely related sectors, every additional dime added to the price of gasoline and diesel oil per gallon, sustained over a year, costs U.S. agriculture almost $400 million annually. Every dollar added to the price per 1,000 cubic feet of natural gas costs agriculture over $200 million annually in direct expense, and costs the fertilizer industry almost $500 million annually. Every dime increase in the price of propane costs agriculture over $200 million per year. Every penny increase in the price per kilowatt-hour of purchased electricity costs agriculture about $500 million annually in direct expense, and also adds about $35 million to the costs of the nitrogenous fertilizer industry.

Mr. COLLINS.  Early in my career, we used to always say that truck transportation was 3 times as expensive as rail, and rail was 3 times as expensive as barge. So if rail or barge wasn’t available, you did truck. If it was between rail and barge, you did barge. But that is not so true anymore. Because of the high energy prices, because of the demand, because of an economy that grew at 3.8 % last quarter, there has just been tremendous demand for all modes of transportation.

As far as farmers that would be exiting agriculture or unable to finance their operations,  I can’t answer that question. There are too many factors that determine whether someone is going to go out of business or not. You can’t take a change in energy costs in 1 year and translate that into somebody leaving the business. American agriculture is incredibly diverse. People have tremendous sources of income outside of farming. Farm income accounts for 13 percent of total household income of all 2.1 million farms, so they have other sources of income to draw on if they wanted to stay in business.

SENATOR TOM HARKIN, IOWA.  Our inland waterways transport 16 % of our goods, at 2 % of the cost of fuel usage. So it is very efficient, very effective.

Senator TALENT.  I think the ability of our producers to continue to produce the safest and most abundant and highest quality food supply in the world is not just an economic issue. It is a national security issue. I don’t want to be in a position where we are importing food the way we import oil. And part of that means, when there is some extraordinary hit on the farm sector, we should ameliorate a little bit some of the costs that they have had to take because of that. I don’t view that from an ideological perspective. For me, that is just a question of trying to protect the food security of the people of the country. To say it is unprecedented, is factually incorrect.

Mr. COLLINS.   I think providing a payment for energy price increases that would affect farmers like they affect every other business in America, like every other household in America—would be unprecedented. I think that would be unprecedented. Certainly, in the disasters that you spoke about, we did provide assistance. And those were focused on agriculture and on crop losses; and they were special, localized, specific disasters. We face a $5 billion increase in energy costs in agriculture this year. We are predicting next year we will face a $2 billion increase in interest costs. Interest is an input just like energy is an input. So how do you distinguish covering interest rate increases from energy increases, when this would be a national impact that affects everybody; not just unique to agriculture?

DANIEL T. KELLEY, National Council of Farmer Cooperatives, Normal, Illinois, on behalf of the AG Energy Alliance 

U.S. agriculture and related agribusinesses use natural gas for irrigation, crop drying, food processing, crop protection, and nitrogen fertilizer production.

Since 2002, 36% of the U.S. nitrogen fertilizer industry, which uses natural gas as a raw material, has been either shut down or mothballed. According to the U.S. Department of Agriculture, farmers’ fuel, oil, and electricity expenses have increased from $8.6 billion to $11.5 billion, from the period 1999 to 2005. Over that same period, fertilizer expenditures went from $9.9 billion to $11.5 billion. Combined, these expenditure increases represent a $4.5 billion decline in U.S. farmers’ bottom line over that 6–year period. The U.S. chemical industry has been especially hard hit by high energy prices, since natural gas is needed as a feedstock. Its natural gas costs increased by $10 billion since 2003, and $40 billion of business has been lost to overseas competitors, who pay much less for natural gas. Chemical companies closed 70 facilities in the United States in 2004 alone, and at least 40 more have been tagged for shutdown. Of the 120 chemical plants being built around the world with price tags of $1 billion or more, only one of those is being built in the U.S. Our Nation’s current natural gas crisis has two solutions: to increase supply; and second, to reduce demand. The challenge is to find ways to balance our Nation’s dwindling available supply of, and rising demand for, natural gas.

Congress can adopt measures to ensure potential Federal lands and Outer Continental Shelf areas are open for leasing; that leases and permits are issued promptly; that the appropriate tax and royalty policies are in place; and that the necessary pipeline infrastructure is available to bring supplies to market; while leaving behind as small an environmental impact as possible. The agriculture community believes that it is strategically critical for Congress to remove these production barriers now, to provide new sources of natural gas and oil supplies.

RICHARD CALHOUN, VICE PRESIDENT, GRAIN AND OILSEED SUPPLY CHAIN—NORTH AMERICA, CARGILL INCORPORATED; ON BEHALF OF THE NORTH AMERICAN EXPORT GRAIN ASSOCIATION, AND THE NATIONAL GRAIN & FEED ASSOCIATION

The transportation system in the United States has for many decades been one of the true competitive strengths of U.S. agriculture. For a number of reasons, this asset has turned from a potential strength to a potential weakness. Higher energy costs, congestion on railroads and highways, lack of investment in modernizing and maintaining the inland waterway system, as well as the recent storm-related problems, are combining to sharply escalate the costs of moving agricultural products to market.

The U.S. transportation system serving agriculture, including barges, railroads, and trucks, was running at virtually full capacity at the time Katrina struck the United States. The loss in transport capacity from that storm proved how vulnerable the U.S. is to such disruptions.

Barge transportation is 2.5 times as fuel efficient as rail movements, and almost nine times as efficient as trucking product. So as energy is likely to remain expensive, and energy conservation is a national goal, the time is nigh to begin seriously investing in modernizing the commercial navigation system.

NEAL ELLIOTT, PH. D., P.E., INDUSTRIAL & AGRICULTURAL PROGRAM DIRECTOR, AMERICAN COUNCIL FOR AN ENERGY-EFFICIENT ECONOMY

America, I would say, is in an energy straitjacket right now.  It will take several years, if not longer, to make significant expansion in energy resources. However, there is one resource that is available to us today, and that is energy efficiency and conservation. This is a resource that we can bring to the market both quickly and cost effectively. And we have seen several examples of those in recent years. In California and New York in 2001, energy efficiency and conservation played a major role in reducing demand and rebalancing energy markets; which avoided major economic losses.

RYAN NEIBUR, ROCKY MOUNTAIN FARMERS UNION, BURLINGTON, COLORADO.   The price of natural gas has increased 215 % in the last 3 years. This increase has raised my cost of irrigation per crop year from $50 an acre in 2003, to $158 expected in 2006. At this rate, farmers will not be able to afford irrigation, and will be forced to dry-land farm in an area that has been in a drought for 5 years. In my situation, dry-land farming irrigated ground is not an option with my bank.

Natural gas is the main ingredient used to make anhydrous ammonia and liquid nitrogen. In 2003, we paid $295 a ton, compared to $495 a ton in 2005. In the production of our corn crop, this price increase translates into a cost-per-acre change of $37–per-acre in 2003, to $62–an-acre in 2005; almost doubling the cost.

In December 2003, I paid $1.10 a gallon for farm fuel. In October 2005, I paid $2.85 a gallon, for the same farm fuel; an increase of over 155 percent. On my farm, fuel expense has gone from $60,700 in 2004, to over $135,000 in 2005. If you put this into a per-acre basis, it is extremely scary. Fuel cost for harvesting corn in 2004 was costing $9.80 per acre. In 2005, fuel cost for harvesting this year was over $22 per acre. Remember, the price of corn has not increased; nor has the yield. Farmers and ranchers are in a situation that does not allow us to pass on these additional costs as a surcharge; which other industries, such as truck lines and airlines, are able to do.

As a farmer, I have no means by which to pass on the higher costs of energy. And it seems that Congress should consider approving some type of mechanism to help farmers and ranchers offset these higher costs.

NFU has been a longtime advocate for renewable fuel standards and renewable bio-based fuels. And we believe that more efforts need to be made to produce fuel and energy from our farms.

 

 

 

 

Posted in Transportation, Trucks, U.S. Congress Energy Dependence, U.S. Congress Transportation | Comments Off on Agricultural Transportation and Energy Issues. Senate hearing 2005.

Doomsday: Will peak phosphate get us before global warming?

Price, Ed.  July 22, 2013. Doomsday: Will Peak Phosphate Get us Before Global Warming? oilprice.com

Although climate change catches the headlines, it is not the only doomsday scenario out there. A smaller but no less fervent band of worriers think that peak phosphate—a catastrophic decline in output of an essential fertilizer—will get us first.

One of the worriers is Jeremy Grantham of the global investment management firm GMO. Grantham foresees a coming crash of the earth’s population from a projected 10 billion to no more than 1.5 billion. He thinks the rest of humanity will starve to death because we are running out of phosphate fertilizer. This post on Business Insider from late last year provides an array of alarming charts to back up his warning.

Foreign Policy agrees that phosphate shortages are a potential threat. “If we fail to meet this challenge,” write contributors James Elser and Stuart White, “humanity faces a Malthusian trap of widespread famine on a scale that we have not yet experienced. The geopolitical impacts of such disruptions will be severe, as an increasing number of states fail to provide their citizens with a sufficient food supply.”

What is going on here? Is this really “the biggest problem we’ve never heard of,” as Elser puts it? Or are phosphate shortages something that global markets can cope with? Let’s take a closer look.

Why we need phosphates and why we are trouble if they run out

The element phosphorus is as essential to life as carbon or oxygen. It forms part of the structure of cell walls and DNA without which no plant or animal can exist. Phosphates are phosphorus in chemical forms that are available to plants. Some phosphates occur naturally in the soil as the result of weathering of rocks, but since the dawn of agriculture, farmers have added phosphate fertilizers to increase crop production. Manure, the traditional source, still accounts for about 15 percent of all phosphates used in agriculture, but since mid- twentieth century, most such fertilizer has come from phosphate rock.

What we appear to be running out of are deposits of phosphate rock that can be mined at reasonable cost with today’s technology. Up to now, the United States has been a big producer, but its reserves are declining. China has a lot, but its domestic use is soaring and it is not a big exporter. North Africa has the biggest reserves, but some of them are in politically unstable regions like the Western Sahara.

The following widely reproduced diagram from a 2009 paper in Global Environmental Change depicts the peak phosphorus hypothesis in the form of a “Hubbert curve” that shows production declining at an accelerating rate after hitting a maximum around 2035. After that, say peak phosphate proponents, we are in big trouble.

Peak Phosphorus

Can the market save us?

Yes, a shortage of phosphates could spell trouble, but don’t forget about markets. Adjusting to shortages is just what markets are for. As economists see it, depleting a resource like phosphate rock is supposed to cause its price to rise. As the price rises, two things are supposed to happen. First, users are supposed to figure out ways to get by with less, and second, producers are supposed to find new sources of supply. Will this happen in the case of phosphates, or do they have unique properties that will prevent markets from working their magic?

Some think the latter. For example, the authors of the peak phosphorus diagram write that:

“a key difference between peak oil and peak phosphorus, is that oil can be replaced with other forms of energy once it becomes too scarce. But there is no substitute for phosphorus in food production. It cannot be produced or synthesized in a laboratory. Quite simply, without phosphorus, we cannot produce food.”

Fortunately, the biological impossibility of substituting some other element for phosphorus in food production is not enough to thwart the operation of supply and demand in the phosphate market. One sign that the market is working is that phosphate prices are already rising. As the following chart shows, the U.S. prices of two of the most commonly used phosphate fertilizers soared in the early 2000s. Along with the prices of many other commodities, they dropped back from their peaks after the global financial crisis, but they are heading up again as the economy recovers.

Phosphate Fertilizers

The price increases have already had an impact on phosphate use. As the next chart shows, despite rising farm output, the growth rate of phosphate fertilizer use has slowed over time. The question for the future is whether it is technically feasible to increase food output further while actually reducing phosphate use.

Phosphate Use

Experts appear to think the answer is yes. A report published in Environmental Research Lettersestimates that improvements in farm management practices and consumer waste could cut the phosphates needed to produce the present U.S. farm output by half, even with today’s technologies. In the future, even greater reductions may be possible. According to Roberto Gaxiola of Arizona State University, generations of phosphate fertilizer use have reduced the efficiency of phosphorus uptake by domesticated crop plants. His experiments indicate that selective breeding and genetic engineering can produce plants that can flourish with much lower phosphorus use.

There are significant developments on the supply side, as well. Michael Mew of the Fertecon Research Centernotes that producers are already learning how to upgrade lower quality phosphate rock reserves and are modifying processing plants to accept lower quality inputs. Also, he notes that increasing vertical integration of the industry has resulted in a reduction in transportation costs. Those cost savings slow the rate of price increase and give more time for supply and demand to adjust.

Furthermore, although it is true that we cannot create or synthesize phosphorus, we can recover useable phosphorus from waste streams, including urban sewage. As this source explains, existing systems already remove phosphorus from sewage in order to preserve water quality in the rivers and streams into which they discharge treated waste. Given the low prices for phosphate that prevailed until recently, it did not pay to recover that phosphorus in usable forms. Much of it has ended up as sludge buried in landfills. However, several methods could recover a high percentage of the phosphorus from wastewater. At some price, doing so will become a profitable alternative to producing phosphate fertilizers from increasingly low-grade phosphate rock. It may even become worthwhile to mine phosphate from sewage sludge buried in old landfills.

The bottom line

The problems posed by depletion of finite supplies of high-grade phosphate rock are not trivial. However, it is highly misleading to forecast a sharp peak of phosphate fertilizer production in the near future, let alone to predict that mass starvation and population collapse lie on the downslope of the curve. The fact that there are no substitutes for phosphorus when it comes to building DNA or cell walls does not mean that markets are incapable of managing increasing scarcity.

What does seem likely is a period of continued high or rising phosphate prices, which will trigger three reactions. First, higher prices will make it economical to process ever-lower grades of phosphate rock. Second, they will spur changes in farm management and development of improved crop varieties; these in turn will accelerate incipient trends toward increased food output per unit of phosphate input. Third, higher prices will provide incentives for improved recycling of phosphorus from waste streams.

Putting all this together, Michael Mew dismisses the peak phosphate hypothesis. Instead, he foresees a phosphate plateau as higher prices cause historical growth rates to level off gradually.

Phosphate Produstion

Such a phosphate plateau does not preclude the need for changes in how people live and eat. It could well mean the relative price of food will rise over time, something that could cause hardship for many of the world’s poor. Furthermore, the price of phosphorus-intensive meat is likely to rise relative to those of other foods, making it unrealistic for the world’s emergent middle classes ever to attain the kind of meat-rich diet to which residents of today’s wealthy countries have become accustomed—a diet that, in the age of obesity,  is sometimes less of a blessing than a curse.

When all is said and done, a plateau is not a cliff. There is no phosphate doomsday on the horizon.

Posted in Peak Phosphorus | Tagged | 2 Comments

Sand mines used to frack oil & gas are destroying the best topsoil in the Midwest

Preface. Frac sand is a high-purity quartz sand that is injected into wells to blast and hold open cracks in the shale rock layer during the fracking process. In the United States, frac sand is being mined intensively from sandstone deposits across large swaths of land in Wisconsin, Illinois, Minnesota, and Michigan. With the sand, however, comes a number of air, water, public health concerns. These include but are not limited to displacing agricultural lands and ecologically sensitive ecosystems, damaging surface water, like streams, and introducing silica sand into the air, which is a human health hazard.

It is still having shortages in 2022: As oil prices soar, U.S. drillers scramble to find sand for fracking, Sand for fracking is now 3 times as expensive as it was last year, and it’s one of several reasons US oil production isn’t increasing

Alice Friedemann  www.energyskeptic.com  Author of Life After Fossil Fuels: A Reality Check on Alternative Energy; When Trucks Stop Running: Energy and the Future of Transportation”, Barriers to Making Algal Biofuels, & “Crunch! Whole Grain Artisan Chips and Crackers”.  Women in ecology  Podcasts: WGBH, Jore, Planet: Critical, Crazy Town, Collapse Chronicles, Derrick Jensen, Practical Prepping, Kunstler 253 &278, Peak Prosperity,  Index of best energyskeptic posts

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Nancy C. Loem. May 23, 2016. The sand mines that ruin farmland.  New York Times.

Chicago — While the shale gas industry has been depressed in recent years by low oil and gas prices, analysts are predicting that it will soon rebound. Many of the environmental hazards of the gas extraction process, called hydraulic fracturing or fracking, are by now familiar: contaminated drinking water, oil spills and methane gas leaks, exploding rail cars and earthquakes.

A less well-known effect is the destruction of large areas of Midwestern farmland resulting from one of fracking’s key ingredients: sand.

Fracking involves pumping vast quantities of water and chemicals into rock formations under high pressure, but the mix injected into wells also includes huge amounts of “frac sand.” The sand is used to keep the fissures in the rock open — acting as what drilling engineers call a “proppant” — so that the locked-in oil and gas can escape.

Illinois, Wisconsin and Minnesota are home to some of the richest agricultural land anywhere in the world.

But this fertile, naturally irrigated farmland sits atop another resource that has become more highly prized: a deposit of fine silica sand known as St. Peter sandstone. This particular sand is valued by the fracking industry for its high silica content, round grains, uniform grain size and strength. These qualities enable the St. Peter sand to withstand the intensity of fracking, and improve the efficiency of drilling operations.

In the Upper Midwest, this sandstone deposit lies just below the surface. It runs wide but not deep. This makes the sand easy to reach, but it also means that to extract large quantities, mines have to be dug across hundreds of acres.

At the end of 2015, there were 129 industrial sand facilities — including mines, processing plants and rail heads — operating in Wisconsin, up from just five mines and five processing plants in 2010. At the center of Illinois’s sand rush, in LaSalle County, where I am counsel to a group of farmers that is challenging one mine’s location, The Chicago Tribune found that mining companies had acquired at least 3,100 acres of prime farmland from 2005 to 2014.

In the jargon of the fracking industry, the farmland above the sand is “overburden.” Instead of growing crops that feed people, it becomes berms, walls of subsoil and topsoil piled up to 30 feet high to hide the mines.

But the effects cannot be hidden indefinitely. These mines are destroying rural communities along with the farmland. Homesteads and small towns are being battered by mine blasting, hundreds of diesel trucks speed down rural roads dropping sand along the way, stadium lighting is so bright it blots out the night sky, and 24-hour operations go on within a few hundred feet of homes and farms. As a result, some farmers are selling and moving away, while for those determined to stay, life is changed forever.

Quality of life is not their only concern. Silica is a human carcinogen and also causes lung disease, including silicosis. Because of its dangers, silica is heavily regulated in the workplace, but there are generally no regulations for silica blown around from the sand-mining operations. These mines also use millions of gallons of groundwater every day. Local wells are running dry, and the long-term availability of water for homes and farms is threatened.

Because of the recent slowdown in the fracking industry, many of the sand mines stopped or slowed production, providing temporary respite to these rural communities. But with oil edging back up toward $50 a barrel, and projected to go higher, the Midwest farmlands face a renewed threat.

The sand mines do promise jobs. But it’s shortsighted to rely on a new fracking boom when we’ve already seen how vulnerable the business is to cyclical dips. America’s frac sand industry shrank to about $2 billion last year from $4.5 billion after the price of oil plummeted in 2014. As mines were mothballed or shuttered, hundreds of miners and truckers were laid off.

Even assuming a coming recovery, there may be as few as 20 to 30 jobs in a mine covering hundreds of acres — a mine that may operate for only 20 years. When the sand is exhausted, the mine is a hole in the ground and the jobs are gone. The farms that it replaced provided employment and sustenance for centuries.

There are alternatives to this despoliation. Not all frac sand is buried under prime farmland. Texas, Kansas, Arkansas and Oklahoma all have usable frac sand that is not “burdened” by rich prairie earth, and transportation costs there are often lower.

In the Midwest, we badly need more legal restraints on how frac sand mines operate. People must be protected from blowing silica. Sand piles should be covered and mines set a safe distance from homes, farms, schools and public spaces. At present, such regulations are often lax, and local residents have rarely won the needed protections from local or state governments eager to cash in on the boom.

Groundwater, too, needs stronger safeguards. A good example to follow is LaSalle County, which in 2013 placed a moratorium on new high-capacity wells needed for mining pending the results of a United States Geological Survey study in part funded by Northwestern, where I teach, of the capacity of groundwater supplies to support new mines.

Unfettered frac sand mining is ruining the rural communities of the Midwest. All people are left with are thousands of acres of holes in the ground in place of what was once rich, productive farmland. That is too high a price to pay.

Posted in Oil & Gas Fracked, Peak Sand, Soil | Tagged , , , | 3 Comments

HSBC bank report predicts another financial crisis in 2018

[ Bill Hill of the Hill’s group predicted in June 2016 (at a peakoil.com forum): “We expect to have reached permanent depression by the end of 2017. The reduction will not hit all nations the same way. The richer Western countries will be able to afford fuels for longer than smaller poorer counties. But, how that will feed back into their general economies is yet an unknown. It will definitely have a negative impact, and perhaps a gigantic one. Like the S&P collapsing, an explosion of corporate bankruptcies, and supply chains breaking. But all and all we will just have to wait and see. It has been four years since petroleum hit its energy half way point. We should not have to wait much longer. ]

Is an Economic Oil Crash Around the Corner? By Nafeez Ahmet, January 2017, Alternet.

A report by HSBC shows that contrary to industry mythology, even amidst the glut of unconventional oil and gas, the vast bulk of the world’s oil production has already peaked and is now in decline, while European government scientists show that the value of energy produced by oil has declined by half within the first 15 years of the 21st century.

The upshot? Welcome to a new age of permanent economic recession driven by ongoing dependence on dirty, expensive, difficult oil—unless we choose a fundamentally different path.

Last September, a few outlets were reporting the counter intuitive findings of a new HSBC research report on global oil supply. Unfortunately, the true implications of the HSBC report were largely misunderstood.

New scientific research suggests that the world faces an imminent oil crunch, which will trigger another financial crisis.

The HSBC research note — prepared for clients of the global bank — found that contrary to concerns about too much oil supply and insufficient demand, the situation was opposite: global oil supply in coming years will be insufficient to sustain rising demand.

Yet the full, striking import of the report, concerning the world’s permanent entry into a new age of global oil decline, was never really explained. The report didn’t just go against the grain of the industry’s hype about “peak demand”: it vindicated what is routinely lambasted by the industry as a myth: peak oil ,  the concurrent peak and decline of global oil production.

The HSBC report you need to read

Insurge Intelligence obtained a copy of the report in December 2016, and for the first time we are exclusively publishing the entire report in the public interest. Read and/or download the full HSBC report.

Headquartered in London, HSBC is the world’s sixth largest bank, holding assets of $2.67 trillion. So when it produces a research report for its clients, we should listen. Among the report’s most shocking findings is that, “81% of the world’s total liquids production is already in decline.”

Between 2016 and 2020, non-OPEC production will be flat due to declines in conventional oil production, even though OPEC will continue to increase production modestly. This means that by 2017, deliverable spare capacity could be as little as 1% of global oil demand.

This heightens the risk of a major global oil supply shock around 2018 which could “significantly affect oil prices.”

The report asserts that peak demand (the idea that demand will stop growing leaving the world awash in too much supply), while certainly a relevant issue due to climate change agreements and disruptive trends in alternative technologies, is not the most imminent challenge:

“Even in a world of slower oil demand growth, we think the biggest long-term challenge is to offset declines in production from mature fields. The scale of this issue is such that in our view rather there could well be a global supply squeeze some time before we are realistically looking at global demand peaking.”

Under the current supply glut driven by rising unconventional production, falling oil prices have damaged industry profitability and led to dramatic cut backs in new investments in production. This, HSBC says, will exacerbate the likelihood of a global oil supply crunch from 2018 onwards.

Four Saudi Arabias, anyone?

The HSBC report examines two main datasets from the International Energy Agency and the University of Uppsala’s Global Energy Systems Program in Sweden.

The latter has consistently advocated a global peak oil scenario for many years — the HSBC report confirms the accuracy of this scenario, and shows that the IEA’s data supports it.

The rate and nature of new oil discoveries has declined dramatically over the last few decades, reaching almost negligible levels on a global scale, the report finds. Compare this to the report’s warning that just to keep production flat against increasing decline rates, the world will need to add four Saudi Arabia’s worth of production by 2040. North American production, despite remaining the most promising in terms of potential, will simply not be able to fill this gap.

Business Insider, the Telegraph and other outlets that covered the report last year acknowledged the supply gap, but failed to properly clarify that HSBC’s devastating findings basically forecast the long-term scarcity of cheap oil due to global peak oil, from 2018 to 2040.

The report revises the way it approaches the concept of peak oil — rather than forecasting it as a single global event, the report uses a disaggregated approach focusing on specific regions and producers. Under this analysis, 81% of the world’s oil supply has peaked in production and so now “is post-peak.”

Using a more restrictive definition puts the quantity of global oil that has peaked at 64%. But either way, well over half the world’s global oil supply consists of mature and declining fields whose production is inexorably and irreversibly decreasing:

“If we assumed a decline rate of 5%pa [per year] on global post-peak supply of 74 mbd — which is by no means aggressive in our view — it would imply a fall in post-peak supply of c.38mbd by 2030 and c.52mbd out to 2040. In other words, the world would need to find over four times the size of Saudi Arabia just to keep supply flat, before demand growth is taken into account.”

What’s worse is that when demand growth is taken into account — and the report notes that even the most conservative projections forecast a rise in global oil demand by 2040 of more than 8 mbd above that of 2015 — then even more oil would be needed to fill the coming supply gap.

But with new discoveries at an all-time low and continuing to diminish, the implication is that oil can simply never fill this gap.

Technological innovation exacerbates the problem

Much trumpeted improvements in drilling rates and efficiency will not make things better, because they will only accelerate production in the short term while, therefore, more rapidly depleting existing reserves. In this case, the report concludes: “the decline-delaying techniques are only masking what could be significantly higher decline rates in the future.”

This does not mean that peak demand should be dismissed as a serious concern. As Michael Bradshaw, professor of global energy at Warwick University’s Sloan Business School, told me for my previous Vice article, any return to higher oil prices will have major economic consequences.

Price spikes, economic recession

Firstly, oil price spikes would have an immediate recessionary effect on the global economy, by amplifying inflation and leading to higher costs for social activity at all levels, driven by the higher underlying energy costs.

Secondly, even as spikes may temporarily return some oil companies to potential profitability, such higher oil prices will drive consumer incentives to transition to cheaper renewable energy technologies like solar and wind, which are already becoming cost-competitive with fossil fuels.

That means a global oil squeeze could end up having a dramatic impact on continued demand for oil, as twin crises of peak oil and peak demand end up intensifying and interacting in unfamiliar ways.

The demise of fossil fuels

But the HSBC report’s specific forecasts of global oil supply and demand are part of a wider story of global net energy decline.

A new scientific research paper authored by a team of European government scientists, published on Cornell University’s Arxiv website in October 2016, warns that the global economy has entered a new era of slow and declining growth. This is because the value of energy that can be produced from the world’s fossil fuel resource base is declining inexorably.

The paper—currently under review with an academic journal—was authored by Francesco Meneguzzo, Rosaria Ciriminna, Lorenzo Albanese, Mario Pagliaro, who collectively conduct research on climate change, energy, physics and materials science at the Italian National Research Council,  Italy’s premier government agency for scientific research.

According to HSBC, oil prices are likely to rise and stabilize for some time around the $75 per barrel mark. But the Italian scientists find that this is still too high to avoid destabilizing recessionary effects on the economy.

The Italian study offers a new model combining “the competing dynamics of population and economic growth with oil supply and price,” with a view to evaluate the near-term consequences for global economic growth.

Data from the past 40 years shows that during economic recessions, the oil price tops $60 per barrel, but during economic growth remains below $40 a barrel. This means that prices above $60 will inevitably induce recession. Therefore, the scientists conclude that to avoid recession, “the oil price should not exceed a threshold located somewhat between $40/b [per barrel] and $50/b, or possibly even lower.”

More broadly, the scientists show that there is a direct correlation between global population growth, economic growth and total energy consumption. As the latter has steadily increased, it has literally fueled the growth of global wealth.

But even so, the paper finds that the world is experiencing: “declining average EROIs [Energy Return on Investment] for all fossil fuels; with the EROI of oil having likely halved in the short course of the first 15 years of the 21st century.”

EROI is the total value of energy a resource can generate, calculated by comparing the quantity of energy extracted, to the quantity of energy put in to enable the extraction.

This means that overall, despite total liquids production increasing, as the energy value it generates is declining, the overall costs of extraction are simultaneously increasing. This is acting as an increasing geophysical brake on global economic growth. And it means the more the economy remains dependent on fossil fuels, the more the economy is tied to the recessionary impact of global net energy decline: “The chance of future economic growth matching the current trajectory of the human population is inextricably bound to the wide and growing availability of highly concentrated energy sources enjoying broad applicability to energy end uses.”

The problem is that since the 1980s, the share of oil in the global energy mix has declined. To make up for this, economic growth has increasingly had to rely on clever financial instruments based on debt: in effect, the world is borrowing from the future to sustain our present consumption levels.

In an interview, lead author Francesco Meneguzzo explained:  “Global conventional oil peaked around the year 2005. All the following supply increase was due to unconventional oil exploitation and, since 2009, basically to U.S. shale (tight) oil, which in turn peaked around March, 2015.

“What looks like to be even more important is the fact that global oil supply has failed to keep the pace with the increase in total energy consumption, which ‘natural’ growth requires to be approximately proportional to population increase, leading to the decline of the oil share in the energy mix. While governments have struggled to fuel their economies with ever increasing energy supply, other sources have steadily replaced oil in the energy mix, such as coal in China. Yet, no other conventional source has proved to be a valuable substitute for oil, hence the need for debt in order to replace the vanishing oil share.”

On a business-as-usual trajectory then, the economy can quite literally never recover — unless it transitions to a truly viable new energy source which can substitute for oil.

“In order to avoid the [oil] price affordable by the global economy falling below the extraction cost, debt piling (borrowing from the future) becomes a necessity, yet it is a mere trick to gain some time while hoping for something positive to happen,” said Meneguzzo. “The reality is that debt, basically as a substitute for oil, does not work to produce real wealth, as apparent for example from the decline of the industry value added as a percentage of GDP.”

Where will this end up?

“Recently, debt has started shrinking, basically because it has failed to generate real wealth. Assuming no meaningful (and fast) transition to renewable energy, the economic growth can only deteriorate further and further.”

Basically, this means, Meneguzzo adds, “delocalizing manufacturing to economies using local, cheaper and dirtier energy sources (such as coal in China) as well as lower wages, further shrinking domestic aggregate demand and fueling a downward spiral of deflation and/or debt.”

Is there a way out? Not within the current trajectory: “Unless that debt is immediately used to exploit renewable sources on a massive scale, along with ‘accessories’ such as storage making them as qualified as oil, social and political derangements, even before an economic crash, look to be unavoidable.”

Crisis convergence

Seen in this broader scientific context, the HSBC global oil supply report provides stunning confirmation that for the most part, global oil production is already in post-peak ,  and that after 2018, this is going to manifest in not simply a global supply shock, but a world in which cheap, high quality fossil fuels is increasingly hard to find.

What will this mean? One possible scenario is that by 2018 or shortly thereafter, the world will face a similar convergence of global crises that occurred a decade earlier.

In this scenario, oil price hikes would have a recessionary affect that destabilizes the global debt bubble, which for some years has been higher than pre-2008 crash levels, now at a record $152 trillion.

In 2008, oil price shocks played a key role in creating pre-crisis economic conditions for consumers in which rising living costs helped trigger debt-defaults in housing markets, which rapidly spiraled out of control.

In or shortly after 2018, economic and energy crisis convergence would drive global food prices up, regenerating the contours of the triple crunch we saw ravage the world from 2008 to 2011, the debilitating impacts of which we have yet to recover from.

2018 is likely to be crunch year for another reason. Jan. 1, 2018 is the date when a host of new regulations are set to come in force, which will “constrain lending ability and prompt banks to only advance money to the best borrowers, which could accelerate bankruptcies worldwide,” according to Bloomberg. Other rules to come in play will require banks to stop using their own international risk assessment measures for derivatives trading.

Ironically, the introduction of similar well-intentioned regulation in January 2008 (through Basel II) laid the groundwork to rupture the global financial architecture, making it vulnerable to that year’s banking collapse.

In fact, two years earlier in July 2006, David Martin, an expert on global finance, presciently forecast that Basel II would interact with the debt bubble to convert a collapse of the housing bubble into a global financial conflagration. Just a month after that warning, I was told by a former senior Pentagon official with wide-ranging high-level access to the U.S. military, intelligence and financial establishment that a global banking collapse was imminent, and would likely occur in 2008.

My source insisted that the event was bound up with the peak of global conventional oil production about two years earlier (which according to the U.K.’s former chief government scientist Sir David King did indeed occur around 2005, even though unconventional oil and gas production has offset the conventional decline so far).

Having first outlined my warning of a 2008 global banking collapse in August 2006, I re-articulated the warning in November 2007, citing Martin’s forecast and my own wider systems analysis at a lecture at Imperial College, London. In that lecture, I predicted that a housing-triggered banking crisis would be sparked in the context of the new era of expensive fossil fuels.

I called it then, and I’m calling it now. Some time after January 2018, we are seeing the probability of a new crisis convergence in global energy, economic and food systems, similar to what occurred in 2008.

Today, we are all supposed to quietly believe that the economy is in recovery, when in fact it is merely transitioning through a fundamental global systemic phase-shift in which the unsustainability of prevailing industrial structures are being increasingly laid bare. The truth is that the cycles of protracted economic crisis are symptomatic of a deeper global systemic process.

One way we can brace ourselves for the next crash is to recognize it for what it is: a symptom of global system failure, and therefore of the inevitable transition to a post-carbon, post-capitalist future. The future we are stepping into simply doesn’t work the way we are accustomed to.

The old, industrial era rules for the dying age of energy and technological super-abundance must be re-written for a new era beyond fossil fuels, beyond endless growth at any environmental cost, beyond debt-driven finance.

This year, we can prepare for the post-2018 resurgence of crisis convergence by planting seeds — however small — for that future in our own lives, and with those around us, from our families, to our communities and wider societies.
Nafeez Ahmed is an investigative journalist and international security scholar. He writes the System Shift column for VICE’s Motherboard, and is the winner of a 2015 Project Censored Award for Outstanding Investigative Journalism for his former work at the Guardian. He is the author of A User’s Guide to the Crisis of Civilization: And How to Save It (2010), and the scifi thriller novel Zero Point, among other books.

Posted in Crash Coming Soon, Economic Decline | Tagged , | Comments Off on HSBC bank report predicts another financial crisis in 2018

Peak coal 2013-2045 — most likely 2025-2030

Preface.  The amount of coal reserves is far less than what the IPCC has assumed in their models, where they used RESOURCES, which is coal that can’t be economically and/or technologically obtained.  Typical economists, they assume humans are so smart they can figure out everything.

Peak oil sets the timetable for peak coal, since coal mining and transport depends on oil.

Signs of peak coal?

2020: The Energy 202: U.S. coal production hit its lowest point in last four decades. Washington Post.  The United States mined 706 million tons of coal in 2019 — the lowest total since 1978. That’s a 7% drop from 2018, continuing a decade-long decline in overall output since the coal-mining sector’s peak production in 2008. Wyoming, the top coal-producing state, saw a 9% drop in 2019. Arizona stopped mining coal altogether. With the coronavirus pandemic leading to a decline in demand for electricity, the U.S. coal sector is on pace for even bigger drop in 2020, with the U.S. Energy Information Administration projecting in a blog post Monday mining levels “comparable with those in the 1960s.”  On the other hand, coal is still the main source for electricity globally, and 70% of world steel production.

Alice Friedemann  www.energyskeptic.com  author of “When Trucks Stop Running: Energy and the Future of Transportation”, 2015, Springer, Barriers to Making Algal Biofuels, and “Crunch! Whole Grain Artisan Chips and Crackers”. Podcasts: Collapse Chronicles, Derrick Jensen, Practical Prepping, KunstlerCast 253, KunstlerCast278, Peak Prosperity , XX2 report

***

Dennis Coyne. March 11, 2016. Coal Shock Model. peakoilbarrel.com

Coal is an important energy resource, but we do not know how the size of the economically recoverable resource that will eventually be recovered. The mainstream view is that there are extensive coal resources that are economically recoverable. But research by Rutledge, Mohr, and Laherrere contradicts this view.

My estimates of the coal URR are based on the work of David Rutledge and Steve Mohr. Recent work by Jean Laherrere has coal URR estimates which are higher than my estimates, his medium scenario (650 Gtoe) is higher than my high case (630 Gtoe) and his estimates are usually conservative. My estimate may be too conservative, though my medium case (URR=510 Gtoe) is somewhat higher than the best estimate of Steve Mohr (465 Gtoe), whose work on coal is the best that I have found.

The average of the best estimate of Mohr and Laherrere’s medium case is about 550 Gtoe, a little higher than my medium case and similar to Laherrere’s low case. Based on the recent work by Laherrere, my best estimate would be 560 Gtoe (570 Gtoe is the average of my medium and high cases and 550 Gtoe is the average of the Mohr and Laherrere medium cases, the average of all 4 is 560 Gtoe).

The peak for world coal output will be sooner than most people think, the range is 2013 to 2045, my estimate is 2025 to 2030 with peak output between 4 and 5 Gtoe/year (2014 output was about 4 Gtoe/year).

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The eventual peak in World fossil fuel output is a potentially serious problem for human civilization. Many people have studied this problem, including Jean Laherrere, Steve Mohr, Paul Pukite (aka Webhubbletelescope), and David Rutledge.

I have found Steve Mohr’s work the most comprehensive as he covered coal, oil, and natural gas from both the supply and demand perspective in his PhD Thesis. Jean Laherrere has studied the problem extensively with his focus primarily on oil and natural gas, but with some exploration of the coal resource as well. David Rutledge has studied the coal resource using linearization techniques on the production data (which he calls logit and probit).

Paul Pukite introduced the Shock Model with dispersive discovery which he has used primarily to look at how oil and natural gas resources are developed and extracted over time. In the past I have attempted to apply Paul Pukite’s Shock Model (in a simplified form) to the discovery data found in Jean Laherrere’s work for both oil and natural gas, using the analysis of Steve Mohr as a guide for the URR of my low and high scenarios along with the insight gleaned from Hubbert Linearization.

In the current post I will apply the Shock model to the coal resource, again trying to build on the work of Mohr, Rutledge, Laherrere, and Pukite.

A summary of URR estimates for World coal are below:blog1603/

The “Laherrere+Rutledge” estimate uses the Rutledge best estimate for the low case and Laherrere’s low and medium cases for the medium and high cases. Laherrere also has a high case of 750 Gtoe for the World coal URR, which seems too optimistic in my opinion. The “high” estimate of Steve Mohr has been reduced from his “Case 3” estimate of 670 Gtoe by 40 Gtoe because I have assumed lignite and black coal resources are lower than his high estimate.

An update of David Rutledge’s estimate using the latest BP data through 2014 gives a URR of about 400 billion tonnes of oil equivalent (Gtoe) for coal. The Rutledge 2009 estimate was about 350 Gtoe.

My initial estimate was in billions of tonnes (Gt) of coal at 800 Gt for the low estimate (a round number near Steve Mohr’s low estimate of 770 Gt) and 1300 Gt for the high estimate (about the same as Steve Mohr’s high estimate), my medium estimate was simply the average of the high and low estimates. I came across Jean Laherrere’s estimate after I had developed my model, surprisingly his medium estimate is a little higher than my guess, which is usually not the case (for other fossil fuels).

I do not have access to discovery data for coal, but based on World Resource estimates gathered by David Rutledge, most coal resources had been discovered by the 1930s. I developed simple dispersive discovery models with peak discovery around 1900 for each of the three cases, these are rough estimates, I only know is that coal was discovered over time. The cumulative coal discovery models in Gtoe are shown in the chart below for the low, medium and high URR cases.

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In each case about 75% of coal discovery was prior to 1940.  Coal resources have been developed very slowly, especially since the discovery of oil and natural gas. As a simplification I assume that the rate that the discovered coal is developed remains constant over time.

A maximum entropy probability density function with a mean time from discovery to first production of 100 years is used to approximate how quickly new proved developed producing reserves are added to any reserves already producing each year. For example a 1000 million tonne of oil equivalent (1 Gtoe) coal discovery would be developed (on average) as shown in the chart below:

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Reading from the chart, about 9 Mtoe of new producing reserves would be developed from this 1850 discovery in 1860 and about 5 Mtoe of new producing reserves would be developed in 1920. About half of the 1000 Mt discovered in 1850 would have become producing reserves by 1920, so the median time from discovery to producing reserve is about 70 years (the mean is 100 years due to the long tail of the exponential probability density function).

The model takes all the discoveries for each year and applies the probability density function (pdf) above to each year’s discoveries (the pdf is 1000 less than shown in the chart because we multiplied the pdf by 1000 to show the new producing reserves in Mtoe.) Then the new producing reserves from each year’s discoveries are simply added together in a spreadsheet, not complicated, just an accounting exercise.  The new producing reserves curve (when everything is added up) is shown below for the medium URR case (510 Gtoe):

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Each year new producing reserves are added to the pool of producing reserves while some of these reserves are produced and become fossil fuel output. This is indicated schematically below:

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If the Fossil fuel output is less than the new producing reserves added in any year, then the producing reserves would increase during that year, if the reverse is true they would decrease.

The fossil fuel output divided by the producing reserves is called the extraction rate.

Using data from David Rutledge for fossil fuel output to 1980 and data from BP’s Statistical Review of World Energy from 1981 to 2014, I extrapolated the extraction rate trend from 2000 to 2014 to estimate future coal output. The chart below shows the discovery curve, new producing reserves curve, and the output curve for the scenario with a URR of 510 Gtoe.

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Note that when new producing reserves are more than output the producing reserves will increase (up to 1986), after 1993 output is higher than the new producing reserves added each year so producing reserves start to decrease. Producing reserves are in the following chart for the medium scenario (URR=510 Gtoe).

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The fall in producing reserves combined with increased World output of coal from 2000 to 2013 required an increase in extraction rates from 1.5% to 2.9%. I assume after 2014 that this increase in extraction rates continues at a similar rate until reaching 4% in 2026 and then extraction rates gradually flatten, reaching 5.1% in 2070.

Clearly I do not know the future extraction rate, this is an estimate assuming recent trends continue. For this scenario with a coal URR of 510 Gtoe output peaks in 2026 at about 4250 Mtoe/year.

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For the low and high URR cases the details of the analysis are covered at the end of the post. The extraction rate trend from 2000 to 2014 was also extended until a peak was reached and then the increase in extraction rates were assumed to lessen until a constant rate of extraction was reached.

The three scenarios(low, medium, and high) are presented in the chart below.

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The low scenario peaks in 2013 at about 4 Gtoe/a, the medium scenario peaks in 2025 at about 4.3 Gtoe/a, and the high scenario peaks in 2045 at about 4.9 Gtoe/a. Note that the medium scenario is not my best estimate, it is simply a scenario between possible low or high URR cases, reality might fall on any path between the high and low scenarios, depending on the eventual URR and extraction rates in the future.

A blog post by Luis de Sousa covered Jean Laherrere’s estimate of future coal output with URR between 550 Gtoe and 750 Gtoe.

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For comparison, I have adjusted my chart (shown above) to have a similar scale as Jean Laherrere’s chart.

Note that only the two higher scenarios in my chart can be roughly compared with the lower two scenarios in Laherrere’s chart (510 compared with 550 Gtoe and 630 compared with 650 Gtoe). My scenarios peak at higher output at a later year and decline more steeply as a result.

The chart below is Steve Mohr’s medium independently dynamic scenario, where supply responds to coal demand.

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The Chart above labelled C Case 2 is figure 5-8 from page 69 of Steve Mohr’s PhD Dissertation, the peak output is 210 EJ/year in 2019 (from Table 5-7 on page 71), Case 2 has a URR of 19.4 ZJ or 465 Gtoe (ZJ=zettajoule=1E21 J). My medium scenario (URR of 21.3 ZJ) has a lower peak output of 180 EJ/year, which occurs 6 years later than Mohr’s scenario. (1 Gtoe=41.868 EJ=4.1868E-2 ZJ).

It is interesting that Jean Laherrere’s larger URR scenario (550 Gtoe) has a peak of 4 Gtoe/year, while Mohr’s smaller URR (465 Gtoe) has a peak of 5 Gtoe/year. Mohr’s scenario was created in 2010 before the 2014 slowdown in Chinese coal consumption and he may have assumed that China and India would resume their rapid increase in coal consumption from 2010 to 2025. Jean Laherrere’s scenario was created in 2015 and in his 550 Gtoe scenario he may assume that the recent decrease in World coal output (in 2014) will continue in the future.

My medium scenario (510 Gtoe) is between Mohr’s medium (case 2) scenario and Laherrere’s low scenario. I have created two new scenarios using a URR of 510 Gtoe which match the peak output of Laherrere’s 550 Gtoe scenario and Mohr’s 465 Gtoe scenario. I have also created a “plateau” scenario with URR=510 Gtoe with World output remaining at the 2014 level until 2025. The various scenarios are presented in the chart below.

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The extraction rates in the 4 different 510 Gtoe scenarios can be compared in the chart that follows.

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Generally  a higher peak in output leads to steeper annual decline rates, the chart below compares annual decline rates for the 4 different 510 Gtoe URR scenarios.

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Works Cited

  • De Sousa, Luis. “Peak Coal in China and the World, by Jean Laherrère.”          attheedgeoftime.blogspot.com. Web. 11 March. 2016.
  • Mohr, Steve. Projection of world fossil fuel production with supply and demand interactions. 2010. Web. 11 March. 2016.
  • Oil Conundrum. theoilconundrum.com. Web. 11 March. 2016.
  • Rutledge, David. “Estimating long-term world coal production with logit and probit transforms.” International Journal of Coal Geology. 85 (2011): 23-33. Web. 11 March. 2016.

Appendix with details of Low and High cases

With links to Excel files at end of appendix

Low case-URR=390 Gtoe

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High Case- URR=630 Gtoe

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Further reading

Posted in Coal, Peak Coal | Tagged | Comments Off on Peak coal 2013-2045 — most likely 2025-2030

Ugo Bardi: The Hill’s Group report

[ The Hill’s group consists of energy insiders, and I must admit I was impressed by the predictions they said their model had already gotten right, such as the drop in oil price when everyone was expecting the price to rise.  And much of what they say matches the predictions and timeline of others as well as how the net energy cliff will unfold.  The charts and calculus are very impressive, and for years their paper has been discussed on peak oil forums. 

A scientist I know working in Saudi Arabia thinks we’ve got at least 20 years, and that if Exxon, Chevron, and other oil and gas companies go bankrupt, no problem — the government will nationalize them.  Another scientist pointed out that “Modern society runs on oil, thus the oil industry will be the absolute LAST industry to fail. It will be supported by hook or crook until then. Even at $200 a barrel we get energy a thousand times cheaper than human labor. Just not 20,000 times as much anymore”.

Dennis Coyne, who published Seppo Korpela’s article here says: “Oil prices are not determined primarily by thermodynamics as the Hill’s Group suggests.  Geology and technology will affect the cost to supply the oil and World economic growth and technology will affect the demand for oil, the price of oil will mostly be determined by these factors along with policy and political choices made by individual nations.”

After Bardi’s post I’ve added some of the predictions Bill Hill said their model predicted on various forums — many sound plausible, but perhaps not an outcome of their model…  And at the very bottom, an English translation of one of the Spanish articles.  Stay tuned for a peer-reviewed critique of their paper, which I’ve heard is in the works.

Alice Friedemann   www.energyskeptic.com  author of “When Trucks Stop Running: Energy and the Future of Transportation”, 2015, Springer and “Crunch! Whole Grain Artisan Chips and Crackers”. Podcasts: Practical Prepping, KunstlerCast 253, KunstlerCast278, Peak Prosperity , XX2 report ]

Ugo Bardi. Feb 26, 2017. Catastrophism is popular, but not necessarily right. Debunking the “Hill’s Group” analysis of the future of the oil industry. Cassandra’s Legacy.

“The Hill’s Group” has been arguing for the rapid demise of the world’s oil industry on the basis of a calculation of the entropy of the oil extraction process. While it is true that the oil industry is in trouble, the calculations by the Hill’s group are, at best, irrelevant and probably simply plain wrong. Entropy is an important concept, but it must be correctly understood to be useful. It is no good to use it as an excuse to pander unbridled catastrophism. 

Catastrophism is popular. I can see that with the “Cassandra’s Legacy” blog. Every time I publish something that says that we are all going to die soon, it gets many more hits than when I publish posts arguing that we can do something to avoid the incoming disaster. The latest confirmation of this trend came from three posts by Louis Arnoux that I published last summer (link to the first one). All three are in the list of the ten most successful posts ever published here.

Arnoux argues that the problems we have today are caused by the diminishing energy yield (or net energy, or EROI) of fossil fuels. This is a correct observation, but Arnoux bases his case on a report released by a rather obscure organization called “The Hill’s Group.” They use calculations based on the evaluation of the entropy of the extraction process in order to predict a dire future for the world’s oil production. And they sell their report for $28 (shipping included).

Neither Arnoux nor the “Hill’s Group” are the first to argue that diminishing EROEI is at the basis of most of our troubles. But the Hill’s report gained a certain popularity and it has been favorably commented on many blogs and websites. It is t is understandable: the report has an aura of scientific correctness that comes from its use of basic thermodynamic principles and of the concept of entropy, correctly understood as the force behind the depletion problem. There is just a small problem: the report is badly flawed.

When I published Arnoux’s posts on this blog, I thought they were qualitatively correct, and I still think they are. But I didn’t have the time to look at the details of the report of Hill’s group. Now, some people did that and their analysis clearly shows the many fundamental flaws of the treatment. You can read the results in English by Seppo Korpela, and in Spanish by Carlos De Castro and Antonio Turiel. [ NOTE: at the very bottom I have an english translation minus the equations ].

Entropy is a complex subject and delving into the Hill’s report and into the criticism to it requires a certain effort. I won’t go into details, here. Let me just say that it simply makes no sense to start from the textbook definition of entropy to calculate the net energy of oil production. The approximations made in the report are so large to make the whole treatment useless (to say nothing of the errors it contains). Using the definition of entropy to analyze oil production is like using quantum mechanics to design a plane. It is true that all the electrons in a plane have to obey Schroedinger’s equation, but that’s not the way engineers design planes.

Of course, the problem of diminishing EROEI exists and can be studied. The way to do that is known and it is based on the “life cycle analysis” (LCA) of the process. This method takes into account entropy indirectly, in terms of heat losses, without attempting the impossible task of calculating it from first principles. By means of this method we can see that, at present, oil production still provides a reasonable energy return on investment (EROEI) as you can read, for instance, in a recent paper by Brandt et al.

But if producing oil still provides an energy return, why is the oil industry in such dire troubles? (see this post on the SRSrocco report, for instance). Well, let me cite a post by Nate Hagens:

In the last 10 years the global credit market has grown at 12% per year allowing GDP growth of only 3.5% and increasing global crude oil production less than 1% annually. We’re so used to running on various treadmills that the landscape doesn’t look all too scary. But since 2008, despite energies fundamental role in economic growth, it is access to credit that is supporting our economies, in a surreal, permanent, Faustian bargain sort of way. As long as interest rates (govt borrowing costs) are low and market participants accept it, this can go on for quite a long time, all the while burning through the next higher cost tranche of extractable carbon fuel in turn getting reduced benefits from the “Trade” creating other societal pressures.

Society runs on energy, but thinks it runs on money. In such a scenario, there will be some paradoxical results from the end of cheap (to extract) oil. Instead of higher prices, the global economy will first lose the ability to continue to service both the principal and the interest on the large amounts of newly created money/debt, and we will then probably first face deflation. Under this scenario, the casualty will not be higher and higher prices to consumers that most in peak oil community expect, but rather the high and medium cost producers gradually going out of business due to market prices significantly below extraction costs. Peak oil will come about from the high cost tranches of production gradually disappearing.

I don’t expect the government takeover of the credit mechanism to stop, but if it does, both oil production and oil prices will be quite a bit lower. In the long run it’s all about the energy. For the foreseeable future, it’s mostly about the credit

In the end, it is simply dumb to think that the system will automatically collapse when and because the net energy of the oil production process becomes negative (or the EROEI smaller than one). No, it will crash much earlier because of factors correlated to the control system that we call “the economy”. It is a behavior typical of complex adaptative systems that are never understandable in terms of mere energy return considerations. Complex systems always kick back.

The final consideration of this post would simply be to avoid losing time with the Hill’s report (to say nothing about paying $28 for it). But there remains a problem: a report that claims to be based on thermodynamics and uses resounding words such as “entropy” plays into the human tendency of believing what one wants to believe. Catastrophism is popular for various reasons, some perfectly good. Actually, we should all be cautious catastrophists in the sense of being worried about the catastrophes we risk to see as the result of climate change and mineral depletion. But we should also be careful about crying wolf too early. Unfortunately, that’s exactly what Hill&Arnoux did and now they are being debunked, as they should be. That puts in a bad light all the people who are seriously trying to alert the public of the risks ahead.

Catastrophism is the other face of cornucopianism; both are human reactions to a difficult situation. Cornucopianism denies the existence of the problem, catastrophism (in its “hard” form) denies that it can be solved or even just mitigated. Both attitudes lead to inaction. But there exists a middle way in which we don’t exaggerate the problem but we don’t deny it, either, and we do something about it

A defense of the Hills Group (one of the comments at Cassandra’s Legacy):

Your preference for Life Cycle Analysis over the Thermodynamics of Steady State is just that…your preference. The ETP model includes as a cost the cost of replacing reserves as they are used. The method used in the ETP model is similar to what one might use for a biological system…that is, the parents have to provide for the children…adult birds need to look for caterpillars to feed the young. Now, if, as Hubbert assumed, we have a boundless supply of nuclear energy just waiting in the wings, a Life Cycle study would be appropriate. But since oil is part of the very biological business of keeping humans alive and functioning, there is nothing wrong with the ETP method. Whichever method is used, the user is responsible for understanding the assumptions and applying them appropriately.
*You fail to see that the numbers quoted by Nate Hagens MIGHT just have a more fundamental cause than ‘just because’. If the falling value of energy, and particularly oil, as displayed by the output from the ETP model is correct, then we would expect the numbers that Hagens quotes. Hagens is not ‘disproving’ the ETP model.
*After accusing other people of confusing the EROEI methodology, you fall into the same trap. The ETP model does not claim that EROEI is going below 1. As estimated from the ETP model, the ‘dead state’ is arrived at when the EROEI is around 7 (as I remember). Such numbers are reasonably consistent with what Charles Hall and others have called ‘extended EROEI’. That is, they count the costs beyond the well-head. The ETP methodology estimates that, with a well-head EROEI of 7, we will no longer be able to sustain the industrial economy as it is presently configured.
*While the ETP model does not model the human reaction to the recognition that the economic and social system cannot go on much longer as it has been going for the last decades and centuries, Mr. Hill has been very clear that he thinks the situation is dire. The oil companies could lose enormous amounts of equity values overnight. The recognition would reverberate through the economy and the social system. The ETP model tells us something about the physical world, which we must interpret in terms of the financial and social world.

And FYI, some of the predictions the Hills Group claim that their model predicts for the future:

The 2012 energy half way point, set out by the Etp Model, marked the point where the world started being better off without oil than with it. That conversion will be complete by no later than 2030.

Our model indicates that conventional crude production will fall to 44 mb/d by 2030. Thereafter, it goes into catastrophic decline.

Our analysis indicates that it will probably be in the range of 15 to 20 years after that when the majority of petroleum production will ceaseThe oil age is coming to an end. The Etp Model provides a very important time line; one that informs us that we have at most 14 years to put into place an alternate energy system; one beyond oil. Past that point the world will have fallen into such a deep depression that it will no longer be able to help itself.

We expect to have reached permanent depression by the end of 2017 (prediction made June 2016).

The reduction will not hit all nations the same way. The richer Western countries will be able to afford fuels for longer than smaller poorer counties. But, how that will feed back into their general economies is yet an unknown. It will definitely have a negative impact, and perhaps a gigantic one. Like the S&P collapsing, an explosion of corporate bankruptcies, and supply chains breaking. But all and all we will just have to wait and see. It has been four years since petroleum hit its energy half way point. We should not have to wait much longer. We are likely to see the first major impacts this year!

Things are a lot worse than oil producers are admitting. The Etp Model indicates that in the present price environment that only about 35% of the world’s producers are making money over their full life cycle costs. Their desperation for cash ensures that production will not decline until many of them start to fail. The energy dynamics of the situation point to falling prices until at least 2020. By then much of the world’s petroleum production capacity will be gone forever!

Damage is being inflicted on the industry that will never be repaired. CapEx is being cut everywhere in the industry, and future development is likely to never fully recover. The Etp Model indicates that only about an additional 320 Gb will now ever be extracted. In 2012 petroleum contributed $6.22 trillion to the $16.16 trillion GDP of the US. That contribution will fall by more than half during the next decade.

Very low priced oil is a catastrophe for the petroleum industry, and the world. Whereas the oil age might have staggered forward for another 14 to 15 years, it might all come unglued over the next 5 or 6.

The Etp Model indicates that only about an additional 320 Gb will now ever be extracted.

The industry’s net worth is now declining by 24% per year. If the price decline continues, as expected, trillions of dollars will be lost to bond and equity holders over the next few years. Pension funds, and Sovereign wealth fund will be hit particularly hard.

EROEI

Year EROEI : 1
1945 167.0
1980 30.4
2014 9.1
2015 8.9

At 6.9 : 1 it will have reached its the theoretical limit, or were the PPS (Petroleum Production System) reaches the “dead state”. That will be dependent on its accumulated production, which has had a very consistent rate of increase for the last 100 years. The accumulated production has followed Hubbert’s curve almost exactly; by 2009 it had deviated from that curve by 0.04 Gb. In other words the amount remaining to be extracted is a product of how much has already been removed. Any amount after 1,780 Gb will remain in the ground as it will no longer be able to act as an energy source.

The highest ERoEI crude left in the world is probably coming out of the Middle East and Nigeria; and both of them are about to explode.

Saudi Arabia

When Ghawar will start to collapse has been the subject of heated discussion for a very long time. Looking at its water cut, as reported by Aramco reserve engineers, and the fact that they have been drilling horizontal wells to skim the last few feet off the top of the oil column indicates that it probably won’t be long in coming. A better indication is probably the price. The Affordability Curve gives a pretty good indication as to what is likely to transpire, and The Price of Oil  puts the maximum affordability at:

2015 – $77.28
2016 – 65.94
2017 – 54.18
2018 – 41.16
2019 – 26.88

By the looks of the above graph sometime between 2018 and 2019 the Saudi’s will no longer be able to cover their lifting cost. Once that happens their production will collapse, and they will likely break the peg. My WAG (wild ass guess) would be sometime in that time frame.   Of course, the Iranians may decide to blow the crap out of them at any time, and that would put a real crimp onto their production. It looks like the best case scenario is 2 to 3 years before Saudi Arabia implodes.

Shale / Light Tight Oil

U.S. LTO production will not start to decline because of a lack of drilling opportunities, lack of funds (the FED has their back), or because of high well decline rates. It will decline when it runs out of buyers for it. That will happen in the next couple of years.

It now requires about 74,000 BTU to extract, process, and distribute a gallon of petroleum. Only the lower API fractions have an energy content that is sufficient to provide a surplus of energy after their process energy is subtracted.

The energy dynamics imply that once conventional crude is depleted, that other alternative liquid fuels will not be able to maintain enough of the economy needed to produce them, or provide for their demand. Shale is a good example of this phenomenon. Most shale is incapable of driving the economy, and its only use is as a feedstock for other processes.

Civilization is likely to experience something resembling a brown out. Voltage drops until the motors grind to halt, and burn up. Imagine billions of people milling around trying to figure out why things are running slower, and slower. Not much has yet fully stopped working, but nothing is working quite right!

Petroleum is providing just enough energy at this point in time to keep what is running going. If any additional load is placed on the system, like having to bail out the banks again, a good sized war, or even some natural disaster something is going to burn up. Maybe a big chunk of the health care system, the consumer economy, or the petroleum industry but something will no longer be maintainable. The world no longer has the extra energy to expend on anything but what it is presently using. The danger is that when it starts it could cascade into a black out!

 

An analysis of the theoretical foundations of the ETP model  By Antonio Turiel

Last February 20th,  we held a monographic session in the Transition Forum organized by FUHEM (a Spanish foundation concerned with social issues, basically a NGO of many intellectuals and scarce funds), to analyze the ETP model. This model created by the Hill’s Group tries to forecast the global oil production evolution in the next years. It is based in the decreasing net energy that oil is offering.

To start the discussion, FUHEM asked me to make an analysis to validate and check the theoretical robustness of the said model. They were trying to see, among other things, if their conclusions (quite terrible, by the way) could be used in their discussions with political agents.

 

I have deemed convenient to write this post explaining the conclusions of my analysis, due to its importance and the raising interest on this subject.

 

This is a rather technical post, but I will try to explain the basic concepts in the most intuitive possible form. The formulas and concepts treated are those included in the document “Depletion: A determination for the world’s petroleum reserve”, release 2 of March 1st. 2015.

 

The following critique is not exhaustive; there are many aspects in the model that will not be treated. I will mainly focus on the most relevant theoretical aspects, but not even all of them, and I will deliberately sidestep the discussion on use of data. Carlos de Castro, on his turn, made a detailed analysis for the same session on the data processing in the ETP model. This analysis can be accessed as post in the blog of the Energy, Economy and System Dynamics Group of the Valladolid University.

 

The Hill’s Group Report (hereinafter HGR) states in its introduction that they intend to estimate the energy needed by the oil production and distribution system (so called Petroleum Production system, or PPS) to make its products reach the society and to check if this energy is approaching to the energy efficiency limit, which corresponds with the energy that can be obtained just burning this oil.

 

All the HGR is based on the equations used to calculate the energy needed by the PPS to continue working. This needed energy is called Total Production Energy or ETP. They use some thermodynamic equations to this effect and I will precisely focus my analysis on the theoretical derivation of these equations.

 

Theoretical foundations of the ETP

 

One of the weakest points of the report is the inadequate definition of the validity boundaries.  By the treatment given to the variables, it could be thought that calculations are made at the well head and therefore, that the calculated ETP  refers to the energy spent to just extract the oil. However, as per other considerations, it is mentioned that the calculations include all the PPS.

 

Making a calculation for the whole PPS is a rather complex issue, even introducing simplifying hypothesis, such as taking typical or mean values, as there are a huge amount of mixed processes with different efficiencies. The conditions under which extraction, refining and distribution take place greatly change from one place to another in the planet (the spatial dimension, as quoted to Antonio Serrano in his analysis of these problems).

 

In fact, the biggest problem to tackle the analysis with thermodynamic equations is to define and accurately enclose the limits of the system under study and to be sure that the hypotheses are correctly applied to it. In fact, sometimes implicit hypothesis are included inadvertently. So, one has to be extremely careful with the data handling and with the terms included in the equations.

 

Other conceptual problems observed from the start is that the analysis takes the PPS isolated from the rest of the economy and specifically form other energy sources that could back the oil extraction, (oil could still be interesting when no net energy can be extracted from it due to its possibly bigger added value). That makes the statements on the collapse of the PPS questionable, to say the least. The collapse may finally happen, but it is not unavoidable in pure logic, from what is being theoretically analyzed.

 

The basic variable to derive the ETP is the calculation of the entropy variation rate. As the “entropy” word appears, you can bet that 90% of the readers will just jump over the part of the report with the formulas and go directly to the graphs and the conclusions.

 

This post has precisely the aim to analyze to which extent these equations are physically sound, if they are well applied and to which system they are applied. I will try to make the explanation as simple as possible, complementing each theoretical concept with a more simple explanation. In any case, I recommend the (Spanish speaking) readers with time and will to know about this in more detail, to read an old post of this blog, called “Entropía

 

The first equation introduced in the HGR is a general one, valid for any system, on the entropy variation rate with time:

 

Equation 1.

 

Intimidating, as it appears, this equation shows, in fact, a very simple equality

(Notation: S is the symbol to denote entropy). The first term of the equation is the derivative of entropy with time. This term does not say anything specific, being at the left of the sign equal. The equation is issued to calculate this term in the left side. The terms in the right side will give information on which things change the entropy.

 

(Notation: Q means heat. The dot on top means the variation with (respect) time. T means temperature). The entropy of a given body is intimately associated to its temperature. This term includes all the changes of the entropy produced in the considered system due to heat flows. The sigma letter Σ heading the term is a sum indicating that we have to add all the transferences of associated entropies due to all possible heat flows: there exists an undefined amount of heat sources Qj, each of them associated to a temperature Tj and we have to add all of them (for all the values of j index).

 

(Notation: m is the mass of a substance or a given body and s is the entropy per mass unit of this substance or body; it is also called “specific entropy”). This term is just telling that if there are substances or bodies entering into the system, they bring their entropy with them. The dot on top of the m means variation of the mass of the entering substance or body with time and as in the previous term, it is added over all the possible entering bodies, in this case numbered with the i index.

 

Analog to the previous term, but in this case, referred to the substances or bodies abandoning the system. That’s why the negative sign before the summation, because leaving the system also removes entropy from the total.

 

 

 

 

 

 

This is the last term of the equation and refers to all the changes in the entropy associated to irreversible processes taking place in the system. This term is a complete hotchpotch where it can be included everything that could not be counted in the other terms. That’s why is the most difficult to evaluate.

 

The equation just dissected is correct. It is a general one specifying the different factors contributing to the increase of entropy and it can be applied to any system without exceptions. The problem of this equation is that has an undefined number of terms (the sums could easily contain thousands of terms), which makes hard to use it in practice. When this general equation is applied to simple systems, it is possible to make approximations that allow to simplify it and make it manageable. But each of these approximations implies certain hypothesis that could determine the particular system for which they are of application. This implicit specification of the system of application may happen and pass unnoticed to the person who is applying it, that could even claim that the system of application is another one. This is precisely the case of the ETP model, as we shall see below.

 

The first hypothesis in the HGR is to assume that there are no entering masses in the system; only outgoing masses: the oil flow that leaves the wellhead and enters into the PPS. Besides, there is a simplification, when considering only one temperature, taken in a first approach as the typical temperature of the oil deposits. For the outgoing mass the HGR considers the total oil mass leaving all oil deposits. Therefore, the equation is reduced to the following form:

 

Equation 2.

 

Simplifying sums and substituting the quantities by typical values (or by mean values, the report is not explicit on that) is an approximation, but that is not the main problem of this equation. Such kind of simplification is what in Statistical Mechanics is called “mean field” and is applied to systems containing a large number of parts, all of them with the same type of interaction. The mean field gives a good first approach to the reality, maybe incurring in some degree of error but correctly capturing trends.

 

But the problem is not the mean field approximation. It is that the HGR ignores all type of interactions that a real PPS system has. For instance, all the intense flow of materials (steel, concrete, electronics of many different types, etc.) which are required to build and maintain the wells, to build and repair the distribution system (pipelines, trucks, supertankers, etc.). The report also ignores the intense heat inflows and outflows associated to all these processes. All these interactions are of diverse types and cannot be managed with a mean field approximation. Simply because the system is extremely heterogeneous and there are no mean or typical values that could properly describe such complex systems.

 

I will put an example to make myself better understood.

 

Talking about fusion or freezing temperatures of water is useful in practical terms, even if we could be talking of waters from different origins with different mineral salts diluted and therefore slightly different freezing points. In all cases, we are talking of liquids with homogeneous aspects, suffering similar processes. At the end, all the water samples considered will freeze into ice at approximately the same temperature, with slight differences among them. So, it has some sense to talk of a fusion temperature at zero degrees Celsius, and this allow us to understand how ice behaves.

 

Now, let’s think in a heterogeneous system; one constituted by different parts with different behaviors. One apparently simple like ice cream in a vanilla cornet. If we increase the temperature of the system over the melting point of the ice cream, the ice cream will melt, but it will still be contained within the wafer cone. If we continue increasing the temperature, the water content of the ice cream will eventually evaporate, leaving a viscous mass than then a dry mass. If we still increase the temperatures, the system will burn, but the way it will do it, will depend on the different combustion points; it will depends on how the wafer will be softened, the amount of remaining water in the ice cream, etc.

 

The cornet ice cream system cannot be understood with the temperature changes and even less with a given fusion temperature. All the ice cream cornet interactions are rather complex and to understand how the system behaves it is not enough with assessing the behavior of each part (ice cream and wafer cone) separately; it depends also on how the two parts interact with each other for the particular ice cream and wafer cone under consideration. And if the ice cream cornet is complex, we have to imagine how complex should be all the global production and distribution system.

 

This is the reason why the mean field approach used in the equation above cannot be applied (apart from the fact that there are incoming masses and this term cannot be neglected). The conclusion is that the simplified equation applies to the liquid oil contained in the geological deposits, although the interactions with the rocks are also neglected and they may not be so negligible when, for instance, the reservoir rock is collapsing and cementing when the oil is extracted from its interstices.

 

There is a new formula introduced in this point of the report, even it is not used until later, that confirms that the report refers to liquid oil. The formula tells about the entropy variation for an uncompressible, non-reactive liquid, when its temperature is modified from T1 to T2

 

Equation 3

 

The variable c is the specific (per unit of mass)  heat capacity of a liquid (it is explicitly stated in the report that the constant-volume specific heat equals the pressure-constant specific heat, what means that we are talking about uncompressible liquids. Therefore, this formula has only sense when applied to uncompressible liquids that are not undergoing any type of chemical reaction (nor a phase change, as we shall discuss later). In fact, when this equation is used later one, it evidences that all the derivation of the ETP equation refers to liquid oil.

 

If the first hypothesis is very restrictive and determines the system to which is applied, the second hypothesis has much more implications and is regrettably more inconsistent. It is enounced as follows:

 

Given

 

 

(that is, the entropy variation is diminishing as the outgoing mass is decreasing), so the author of the model concludes that

 

Equation 4

 

There are many problems with this deduction. First, limits of applicability. To obtain Equation 4 we have been told that we can neglect the total entropy variation and the entropy associated to outgoing mass because the outgoing mass flow is decreasing. This means that the formula could only be valid for wells that are already in an advanced terminal decline. This hypothesis is not true if we consider the total global number of wells.

 

Equation 4 is not valid for wells not yet in final decline because even if the entropy change due to heat fluxes equals the entropy change due to irreversible processes when the outgoing mass flow is very low, it does not imply that those two terms are equal at any other time.

 

But the situation is even worse: if the oil outflow tends to zero, not only the entropy will tend to vanish, but also the heat flow (there is less heat to transfer, by lacking its source, the oil still to be extracted) and also the change in entropy due to irreversibility will bend to zero. All four terms from Equation 3 tend to zero in the final terminal decline, and for assuming that some terms become negligible in front of others (they go to zero faster, we could say), a very detailed analysis is required. This analysis is not done in the report.

 

The small detail that on top of equation 4 there is a wrong sign (the entropy variation due to irreversibility should appear with a sign minus, when solving equation 2)  is in fact a minor issue (the entropy transference could be redefined with a different convention of signs).

 

Equation 4 is the starting point to calculate what the report calls “rate of irreversibility production” identified with the letter I and defined as follows:

Equation 5

 

This amount, as per equation 4, corresponds exactly with the heat Q (being rigorous, the variations are the both quantities are equal), so what can be calculated solving this equation is the associated flow of heat. Coming back to the expression of equation 3 and combining it with that of equation 5 (it is exactly what the report does), what they calculate is the heat flow obtained when taking a uncompressible, non-reactive liquid, that does not experiment any phase transition and taking it from a given temperature (the one of the geological deposit) to other (the one at the surface).

 

In this last pirouette, without any theoretical explanation, the heat flow is identified with the specific ETP; that is, per unit of oil mass extracted and surprisingly divided by billions of barrels (Gb), thus obtaining the fundamental formula of the report:

 

Equation 6

 

Where m represent the extracted masses (of oil if with subscript c, and water, if with subscript w) and the letters c represent the specific heat capacity of the substance (oil if with subscript c and water, if with subscript w)

 

It is worth to spend some time analyzing this expression. The important thing is the numerator, because the rest consist in dividing by some quite arbitrary amounts (the extracted mass of oil and the Gigabarrels). The numerator has a form that should sound familiar even to a secondary grade student:

Expression 1. Sensible heat of the oil and water mix.

 

We must remember that the specific heat capacity of a given substance is the amount of heat that has to be given to a gram of it to increase its temperature by 1 degree Celsius. For instance the heat capacity of pure water at 25 º C and normal pressure is one calorie per gram and per centigrade degree, or otherwise, 4.18 joules per gram and centigrade degree. Taking this into account and that the heat capacities of the liquids are “quite” constant (with many nuances), the expression 1 is simply the amount of released heat by a mixture of oil and water when it goes from a temperature TR (that of the deposit) to a T0 (that of the environment). In this point, the problems of this theoretical digression are so numerous that it is difficult to list them all.

 

There is no reason whatsoever to identify this heat flow from the mixture of oil and water leaving a deposit with that of the energy ETP (Etp by definition has to be the energy consumed by the PPS to obtain, refine and distribute oil).

 

It is not just that the theoretical rationale implies only a minimum part of the PPS (oil in the deposit) and that there are errors in the approximations (the direst one that invalids everything, in obtaining  equation 4). It is not only that the HGR only computes the heat derived from the extracted mixture. Even discarding these errors, the ETP, as well as the heat, should be a variable of process, not a variable of state. This means that the amount of energy consumed by PPS  depends on the specific processes used to move from one state to the other. Which has the following logic: we do not use the same energy to extract oil with a specialized brand new drilling machine, that using a more deteriorated and obsolete equipment. We do not incur in the  the same energy consumption when transporting oil by a tortuous and long road, that sending it through a well-maintained pipeline system, etc. etc. That is precisely the difficulty implied by trying to assess the ETP from first principles: it is necessary to know in detail the specific processes used. Besides, these processes can be improved with time (in fact this is what usually happens). Therefore, any attempt to make forecasts has to consider these factors as well as many others (financial, geopolitical technological, or demand) that the report does not even mention.

 

Even from the point of view of evaluating this heat flow (which by the way has a minor importance with respect to many other processes that need to be described)  there are many errors. Specifically, given the fact that the temperature of the deposit is of several hundreds degrees Celsius, it could be assumed that in some point from the deposit and the wellhead, the mix of oil and water could suffer a liquid to gas transition, as the pressure decreases, and the subsequent latent heat should be accounted. In any case this heat flow has no much sense, because the oil does not come out at the deposit temperature (it will be very dangerous, as the contact with the oxygen could lead to a deflagration). There must be a temperature exchange process in the extraction (likely favored by the well design), that will introduce irreversible processes that should be accounted in the last term of the equation (and there are not).

 

It is rather curious to see the water fraction appearing in the last moment of the derivation, when in fact this water is entering basically pumped in from the surface to favor the oil extraction; but it was  precisely the incoming mass term what was the first one to be eliminated in the first simplification. In fact the water inflow also implies a heat flow not considered, of opposite sign to the one considered in the formula, that will probably tend to diminish in the left side of equation 4.

 

The entropy is a variable of state and it characterizes, as such, the state of the system; but knowing just the entropy does not suffice to completely characterize a state; other complementary variables are needed, such as temperature, pressure, internal energy, chemical potentials…That’s why even knowing completely the specific process involved in the ETP for the PPS system, the entropy alone will not be enough for evaluation ETP; other complementary variables that the report does not contemplate will also be required.

 

This flaw is severe: apart from the need to introduce more terms in the sums of equation 1 and making consistent hypothesis, it will be necessary to define a good number of additional equations, as many as the state variables, also containing a good number of terms in each of them. In this sense the ETP model has only scratched the surface of the thermodynamic modeling of the energy required for the continuity of the PPS.

 

Some more observations could be made, but I believe it is crystal clear that there is no theoretical reason for the ETP curve, derived from this thermodynamic model. As such, at most the model could work in an effective way, assuming that the curve resembles the right one and that the model parameters can be adjusted a posteriori to produce meaningful results Therefore, data processing in the model is crucial. Regrettably, data processing has many problems on itself, as described by  Carlos de Castro.. I will leave them out to shorten this post.

 

Discussion of the ETP model.

 

The emergence of the ETP model some months ago raised big expectations among the experts in energy depletion, especially because the convincing nature of a fast collapse of the oil industry. The present strong divestment in upstream by oil companies, that started in 2014 and still lasts today, seems to be in perfect agreement with the problems anticipated with the HGR and with the posts by Louis Arnoux

 

In this sense, the appearance of the report whose theoretical grounds have been discussed here, it is something positive, as it opens a necessary debate on the decline of the net energy to still today reluctant sectors to this type of discussion. On the other hand the application of the thermodynamic principles to the assessment of the net energy limits, it is something that has sense and it seems an interesting path to explore, even if this will imply a very exhaustive and meticulous work, with a good comprehension of the many aspects of the oil industry, to ensure a correct accounting.

 

In the negative side, there are many things: an incorrect application of the theory, wrong deductions, definitions with no physical meaning, defective data processing, lack of interaction with the economy and other energy sources, etc.

Taking into account these deficiencies, it is obvious that the ETP model cannot be used for a serious discussion of the energy depletion problems; at least not until a whole review is made.

 

My work in this post, has been somehow similar (although more informal) than the one I would have made as a peer reviewer if sent to a scientific media. In fact, once the Hill’s Group released the report, it should have been desirable to send it to a scientific journal to be peer reviewed, to be later released and disseminated in the scientific community, general public and stakeholder. Passing this revision would have been a guarantee that the work had been assessed by experts and the results are trustworthy.  I understand the authors may already be working on that. My advice is that they wait for the reviewers to finish and apply the suggested corrections, before giving more publicity to a model that as it is today can only serve to discredit to a community that deserves to be heard more than ever.

 

Personal assessment

 

The appearance of the ETP model has prompted the necessity to endow the community with the adequate models to describe the growing non-linearity of the system, that will be growing if there are no short term reactions to the problems already detected.

 

However, the ETP model has been received with a surprising lack of criticism by the community, in a collective gap in which I myself have participated in some way. It may have happened a confirmation bias: as one colleague said, a brilliant and enlightened physicist, the model started with correct premises and arrived to coherent conclusions; therefore, it was reasonable to expect that the model will work properly.

 

In reality, very few had bothered to calmly analyze the model and point out the deficiencies. I hope this should serve to maintain a critical thinking  and do not accept things that seem to confirm what we believe. All hypothesis must be examined and all the works revised to obtain the highest efficiency, yielding the best results to all of us. I do hope that this post and similar others could contribute to improve the model and to improve our understanding of the troubled way ahead of all of us.

 

Bests.

 

Antonio

 

 

 

 

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Peak Uranium by Ugo Bardi from Extracted: How the Quest for Mineral Wealth Is Plundering the Planet

Figure 1. Cumulative uranium consumption by IPCC model 2015-2100 versus measured and inferred Uranium resources. Figure 1 shows that the next IPCC report counts very much on nuclear power to keep warming below 2.5 C.  The black line represents how many million tonnes of reasonably and inferred resources under $260 per kg remain source: 2016 IAEA redbook Clearly most of the IPCC models are unrealistic. Source: David Hughes (private communication)

Preface. This is an extract of Ugo Bardi’s must read “Extracted” about the limits of production of uranium. You can find plenty of material saying there is are a lot of uranium reserves and resources  left elsewhere (EMD 2019). The problem is, uranium requires fossil fuels to be mined, extracted, and processed, and world oil production peaked in 2018, peak world coal in 2013. If you read my book “When Trucks stop running”, you’ll see why trucks can’t run on electric batteries or overhead wires, and without trucks, civilization collapses, so nuclear electricity is not going to solve the energy crisis, and leaves toxic waste our descendants will have to deal with for hundreds of thousands of years (Alley 2013)

Uranium in the news:

Novikova T (2022) Russia & US Uranium. Counterpunch.org. The United States relies heavily on imported uranium, with Russia supplying about 16 percent. And also 23% of enrichment services are provided by Russia, so total imports may be more than 16%.  Though so many reactors in the U.S. are long past their time of retirement and are shutting down that this may well reduce consumption by 16% or more.  The U.S. only produced 1% of world uranium production, and new permits take years.

July 2016 Water power. Extracting uranium from seawater. Scientific American. Stephen Kung of the DOE’s office of Nuclear Energy said that terrestrial sources of uranium are expected to last for only another 100 to 200 more years. It takes 8 weeks to extract 6 grams of uranium from seawater, or 0.75 grams per day,  It takes 27,000,000 grams to run a 1 gigawatt nuclear power plant for one year, so it would take 98,630 years to extract enough uranium from seawater to run just one nuclear power plant.

Alice Friedemann  www.energyskeptic.com  Author of Life After Fossil Fuels: A Reality Check on Alternative Energy; When Trucks Stop Running: Energy and the Future of Transportation”, Barriers to Making Algal Biofuels, & “Crunch! Whole Grain Artisan Chips and Crackers”.  Women in ecology  Podcasts: WGBH, Planet: Critical, Crazy Town, Collapse Chronicles, Derrick Jensen, Practical Prepping, Kunstler 253 &278, Peak Prosperity,  Index of best energyskeptic posts

***

Bardi, Ugo. 2014. Extracted: How the Quest for Mineral Wealth Is Plundering the Planet. Chelsea Green Publishing.

Although there is a rebirth of interest in nuclear energy, there is still a basic problem: uranium is a mineral resource that exists in finite amounts.

Even as early as the 1950s it was clear that the known uranium resources were not sufficient to fuel the “atomic age” for a period longer than a few decades.

That gave rise to the idea of “breeding” fissile plutonium fuel from the more abundant, non-fissile isotope 238 of uranium. It was a very ambitious idea: fuel the industrial system with an element that doesn’t exist in measurable amounts on Earth but would be created by humans expressly for their own purposes. The concept gave rise to dreams of a plutonium-based economy. This ambitious plan was never really put into practice, though, at least not in the form that was envisioned in the 1950s and ’60s. Several attempts were made to build breeder reactors in the 1970s, but the technology was found to be expensive, difficult to manage, and prone to failure. Besides, it posed unsolvable strategic problems in terms of the proliferation of fissile materials that could be used to build atomic weapons. The idea was thoroughly abandoned in the 1970s, when the US Senate enacted a law that forbade the reprocessing of spent nuclear fuel.

A similar fate was encountered by another idea that involved “breeding” a nuclear fuel from a naturally existing element—thorium. The concept involved transforming the 232 isotope of thorium into the fissile 233 isotope of uranium, which then could be used as fuel for a nuclear reactor (or for nuclear warheads). 48 The idea was discussed at length during the heydays of the nuclear industry, and it is still discussed today; but so far, nothing has come out of it and the nuclear industry is still based on mineral uranium as fuel.

Today, the production of uranium from mines is insufficient to fuel the existing nuclear reactors. The gap between supply and demand for mineral uranium has been as large as almost 50% from 1995 to 2005, though gradually reduced the past few years.

The U.S. mined 370,000 metric tons the past 50 years, peaking in 1981 at 17,000 tons/year.  Europe peaked in the 1990s after extracting 460,000 tons.  Today nearly all of the 21,000 ton/year needed to keep European nuclear plants operating is imported.

The European mining cycle allows us to determine how much of the originally estimated uranium reserves could be extracted versus what actually happened before it cost too much to continue. Remarkably in all countries where mining has stopped it did so at well below initial estimates (50 to 70%). Therefore it’s likely ultimate production in South Africa and the United States can be predicted as well.

Table 1. The European mining cycle allows us to determine how much of the originally estimated uranium reserves could be extracted versus what actually happened before it cost too much to continue. Remarkably in all countries where mining has stopped it did so at well below initial estimates (50 to 70%). Therefore it’s likely ultimate production in South Africa and the United States can be predicted as well.

The Soviet Union and Canada each mined 450,000 tons. By 2010 global cumulative production was 2.5 million tons.  Of this, 2 million tons has been used, and the military had most of the remaining half a million tons.

The most recent data available show that mineral uranium accounts now for about 80% of the demand.  The gap is filled by uranium recovered from the stockpiles of the military industry and from the dismantling of old nuclear warheads.

This turning of swords into plows is surely a good idea, but old nuclear weapons and military stocks are a finite resource and cannot be seen as a definitive solution to the problem of insufficient supply. With the present stasis in uranium demand, it is possible that the production gap will be closed in a decade or so by increased mineral production. However, prospects are uncertain, as explained in “The End of Cheap Uranium.” In particular, if nuclear energy were to see a worldwide expansion, it is hard to see how mineral production could satisfy the increasing uranium demand, given the gigantic investments that would be needed, which are unlikely to be possible in the present economically challenging times.

At the same time, the effects of the 2011 incident at the Fukushima nuclear power plant are likely to negatively affect the prospects of growth for nuclear energy production, and with the concomitant reduced demand for uranium, the surviving reactors may have sufficient fuel to remain in operation for several decades.

It’s true that there are large quantities of uranium in the Earth’s crust, but there are limited numbers of deposits that are concentrated enough to be profitably mined. If we tried to extract those less concentrated deposits, the mining process would require far more energy than the mined uranium could ultimately produced [negative EROI].

Modeling Future Uranium Supplies

Uranium supply and demand to 2030

Table 2. Uranium supply and demand to 2030

Michael Dittmar used historical data for countries and single mines, to create a model that projected how much uranium will likely be extracted from existing reserves in the years to come. The model is purely empirical and is based on the assumption that mining companies, when planning the extraction profile of a deposit, project their operations to coincide with the average lifetime of the expensive equipment and infrastructure it takes to mine uranium—about a decade.

Gradually the extraction becomes more expensive as some equipment has to be replaced and the least costly resources are mined. As a consequence, both extraction and profits decline. Eventually the company stops exploiting the deposit and the mine closes. The model depends on both geological and economic constraints, but the fact that it has turned out to be valid for so many past cases shows that it is a good approximation of reality.

This said, the model assumes the following points:

  • Mine operators plan to operate the mine at a nearly constant production level on the basis of detailed geological studies and to manage extraction so that the plateau can be sustained for approximately 10 years.
  • The total amount of extractable uranium is approximately the achieved (or planned) annual plateau value multiplied by 10.

Applying this model to well-documented mines in Canada and Australia, we arrive at amazingly correct results. For instance, in one case, the model predicted a total production of 319 ± 24 kilotons, which was very close to the 310 kilotons actually produced. So we can be reasonably confident that it can be applied to today’s larger currently operating and planned uranium mines. Considering that the achieved plateau production from past operations was usually smaller than the one planned, this model probably overestimates the future production.

Table 2 summarizes the model’s predictions for future uranium production, comparing those findings against forecasts from other groups and against two different potential future nuclear scenarios.

As you can see, the forecasts obtained by this model indicate substantial supply constraints in the coming decades—a considerably different picture from that presented by the other models, which predict larger supplies.

The WNA’s 2009 forecast differs from our model mainly by assuming that existing and future mines will have a lifetime of at least 20 years. As a result, the WNA predicts a production peak of 85 kilotons/year around the year 2025, about 10 years later than in the present model, followed by a steep decline to about 70 kilotons/year in 2030. Despite being relatively optimistic, the forecast by the WNA shows that the uranium production in 2030 would not be higher than it is now. In any case, the long deposit lifetime in the WNA model is inconsistent with the data from past uranium mines. The 2006 estimate from the EWG was based on the Red Book 2005 RAR (reasonably assured resources) and IR (inferred resources) numbers. The EWG calculated an upper production limit based on the assumption that extraction can be increased according to demand until half of the RAR or at most half of the sum of the RAR and IR resources are used. That led the group to estimate a production peak around the year 2025.

Assuming all planned uranium mines are opened, annual mining will increase from 54,000 tons/year to a maximum of 58 (+ or – 4) thousand tons/year in 2015. [ Bardi wrote this before 2013 and 2014 figures were known. 2013 was 59,673 (highest total) and 56,252 in 2014.]

Declining uranium production will make it impossible to obtain a significant increase in electrical power from nuclear plants in the coming decades.

Here are 7 other posts from this great book:

References

Alley, W. M., et al. 2014. Too Hot to Touch: The Problem of High-Level Nuclear Waste.Cambridge University Press.

EMD. 2019. EMD Uranium (Nuclear minerals and REE) committee annual report. i2massociates.com

Posted in Peak Uranium, Ugo Bardi | Tagged , | 5 Comments

Ward-Perkins “The Fall of Rome: And the End of Civilization”

[ This is a book review of Ward-Perkins “The Fall of Rome: And the End of Civilization“.

What sparked my interest in reading several books on the decline of Rome was when James Howard Kunstler  (KunstlerCast 278) interviewed me about my book “When Trucks Stopped Running” and asked whether I thought there’d be mass migrations at some point of energy decline as supply chains broke. This was certainly one of the reasons that many civilizations fell in 1177 B.C., and our supply chains are far more complex, global, and fragile than they were back gotten.

One of my favorite books in high school was Gibbon’s “Decline and Fall of the Roman Empire”, and I discovered there’s been a tremendous amount of scholarship since then.  Peter Turchin finds the patterns of the rise and fall of nations going back 5,000 years to Mesopotamia, including Rome.  Montgomery’s book “Dirt: The erosion of civilizations” makes the case that loss of topsoil is the main, or one of the main reasons civilizations have fallen, and Perlin’s “A Forest Journey” makes the case that civilizations fell due to deforestation. The Roman Empire lost top soil and was deforested, but evaded crashing for a very long time by making Carthage and Egypt send them massive shipments of food.  

Alice Friedemann   www.energyskeptic.com  author of “When Trucks Stop Running: Energy and the Future of Transportation”, 2015, Springer and “Crunch! Whole Grain Artisan Chips and Crackers”. Podcasts: Practical Prepping, KunstlerCast 253, KunstlerCast278, Peak Prosperity , XX2 report ]

Bryan Ward-Perkins. 2006. The Fall of Rome: And the End of Civilization. Oxford University Press.

Notes from this book follow:

The Germanic invaders of the western empire seized or extorted through the threat of force the vast majority of the territories in which they settled, without any formal agreement on how to share resources with their new Roman subjects. The impression given by some recent historians that most Roman territory was formally ceded to them as part of treaty arrangements is quite simply wrong. Evidence shows that conquest or surrender to the threat of force was definitely the norm, not peaceful settlement.

The city of Rome was repeatedly besieged by the Goths, before being captured and sacked over a 3-day period in August 410.  During one siege the inhabitants were forced to progressively reduce their rations and eat only half the previous daily allowance, and later as scarcity continued, only a third. When there was no means of relief, and their food was exhausted, plague not unexpectedly succeeded famine. Corpses lay everywhere. The eventual fall of the city, according to another account, occurred because a rich lady ‘felt pity for the Romans who were being killed off by starvation and who were already turning to cannibalism’, and so opened the gates to the enemy.’

Unsurprisingly, the defeats and disasters of the first half of the 5th century shocked the Roman world. This reaction can be charted most fully in the perplexed response of Christian writers to some obvious and awkward questions. Why had God, so soon after the suppression of the public pagan cults (in 391), unleashed the scourge of the barbarians on a Christian empire; and why did the horrors of invasion afflict the just as harshly as they did the unjust? The scale of the literary response to these difficult questions, the tragic realities that lay behind it, and the ingenious nature of some of the answers that were produced, are all worth examining in detail. They show very clearly that the fifth century was a time of real crisis, rather than one of accommodation and peaceful adjustment.” It was an early drama in the West, the capture of the city of Rome itself in 410, that created the greatest shock waves within the Roman world. In military terms, and in terms of lost resources, this event was of very little consequence, and it certainly did not spell the immediate end of west Roman power.

The pagans now, not unreasonably, attributed Roman failure to the abandonment by the State of the empire’s traditional gods, who for centuries had provided so much security and success. The most sophisticated, radical, and influential answer to this problem was that offered by Augustine, who in 413 (initially in direct response to the sack of Rome) began his monumental City of God.” Here he successfully sidestepped the entire problem of the failure of the Christian empire by arguing that all human affairs are flawed, and that a true Christian is really a citizen of Heaven. Abandoning centuries of Roman pride in their divinely ordained state (including Christian pride during the 4th century), Augustine argued that, in the grand perspective of Eternity, a minor event like the sack of Rome paled into insignificance.

Most resorted to what rapidly became Christian platitudes in the face of disaster.  In a similar vein and also in early 5th-century Gaul, Orientius of Auch confronted the difficult reality that good Christian men and women were suffering unmerited and violent deaths. Not unreasonably, he blamed mankind for turning God’s gifts, such as fire and iron, to warlike and destructive ends.

Roman military dominance over the Germanic peoples was considerable, but never absolute and unshakeable. The Romans had always enjoyed a number of important advantages: they had well-built and imposing fortifications; factory-made weapons that were both standardized and of a high quality; an impressive infrastructure of roads and harbors; the logistical organization necessary to supply their army, whether at base or on campaign; and a tradition of training that ensured disciplined and coordinated action in battle, even in the face of adversity. Furthermore, Roman mastery of the sea, at least in the Mediterranean, was unchallenged and a vital aspect of supply. It was these sophistications, rather than weight of numbers, that created and defended the empire.

These advantages were still considerable in the 4th century. In particular, the Germanic peoples remained innocents at sea (with the important exception of the Anglo-Saxons in the north), and notorious for their inability to mount successful siege warfare. Consequently, small bands of Romans were able to hold out behind fortifications, even against vastly superior numbers, and the empire could maintain its presence in an area even after the surrounding countryside had been completely overrun.

The Alamans were physically stronger and swifter; Roman soldiers, through long training, more ready to obey orders. The enemy were fierce and impetuous; Roman men quiet and cautious, putting trust in their minds while barbarians trusted in their huge bodies. At Strasbourg discipline, tactics, and equipment triumphed over mere brawn.

However, even at the best of times, the edge that the Romans enjoyed over their enemies, through their superior equipment and organization, was never remotely comparable to that of Europeans in the 19th century using rifles, Gatling and Maxim guns against peoples armed mainly with spears. Consequently, although normally the Romans defeated barbarians when they met them in battle, they could and did occasionally suffer disasters. Even at the height of the empire’s success, in AD 9, three whole legions under the command of Quinctilius Varus, along with a host of auxiliaries, were trapped and slaughtered by tribesmen in north Germany. Some 20,000 men died:

The West was lost mainly through failure to engage the invading forces successfully and to drive them back. This caution in the face of the enemy, and the ultimate failure to drive him out, are best explained by the severe problems that there were in putting together armies large enough to feel confident of victory. Avoiding battle led to a slow attrition of the Roman position, but engaging the enemy on a large scale would have risked immediate disaster on the throw of a single dice. Did the invaders push at the doors of a tottering edifice, or did they burst into a venerable but still solid structure? Because the rise and fall of great powers have always been of interest, this issue has been endlessly debated. Famously, Edward Gibbon, inspired by the secularist thinking of the Enlightenment, blamed Rome’s fall in part on the 4th-century triumph of Christianity and the spread of monasticism: “’a large portion of public and private wealth was consecrated to the specious demands of charity and devotion; and the soldiers pay was lavished on the useless multitudes of both sexes, who could only plead the merits of abstinence and chastity.”

Gibbon’s ideas about the damaging effects of Christianity were fiercely contested at the time; then fell into abeyance. In the 19th and early 20th centuries, the fall of Rome tended to be explained in terms of the grand theories of racial degeneration or class conflict that were then current. But in 1964 the pernicious influence of the Church was given a new lease of life by the then doyen of late Roman studies, A. H. M. Jones. Under the wonderful heading ‘Idle Mouths’, Jones lambasted the economically unproductive citizens of the late empire-aristocrats, civil servants, and churchmen: “the Christian church imposed a new class of idle mouths on the resources of the empire … a large number lived on the alms of the peasantry, and as time went on more and more monasteries acquired landed endowments which enabled their inmates to devote themselves entirely to their spiritual duties.”

In my opinion, the key internal element in Rome’s success or failure was the economic well-being of its taxpayers. This was because the empire relied for its security on a professional army, which in turn relied on adequate funding. The 4th-century Roman army contained as many as 600,000 soldiers, all of whom had to be salaried, equipped, and supplied. The number of troops under arms, and the levels of military training and equipment that could be lavished on them, were all determined by the amount of cash that was available. As in a modern state, the contribution in tax of tens of millions of unarmed subjects financed an elite defense corps of full-time fighters. Consequently, again as in a modern state, the strength of the army was closely linked to the well-being of the underlying tax base. Indeed, in Roman times this relationship was a great deal closer than it is today. Military expenditure was by far the largest item in the imperial budget, and there were no other massive departments of state, such as ‘Health’ or ‘Education’, whose spending could be cut when necessary in order to protect ‘Defense’; nor did the credit mechanisms exist in Antiquity that would have allowed the empire to borrow substantial sums of money in an emergency. Military capability relied on immediate access to taxable wealth.

Invasions were not the only problem faced by the western empire; it was also badly affected during parts of the 5th century by civil war and social unrest.

We know that what the empire required during these years was a concerted and united effort against the Goths (then marching through much of Italy and southern Gaul, and sacking Rome itself in 410), and against the Vandals, Sueves, and Alans (who entered Gaul at the very end of 406 and Spain in 409). What it got instead were civil wars, which were often prioritized over the struggle with the barbarians.

As we have seen, the revolts by the Bacaudae in the West can partly be understood as an attempt by desperate provincials to defend themselves, after the central government had failed to protect them. Roman civilians had to relearn the arts of war in this period, and slowly did so. As early as 407-8 two wealthy landowners in Spain raised a force of slaves from their own estates, in support of their relative the emperor Honorius. But it would, of course, take time to convert a disarmed and demilitarized population into an effective fighting force.

Interestingly, the most successful resistance to Germanic invasion was in fact offered by the least Romanized areas of the empire: the Basque country; Brittany; and western Britain. Brittany and the Basque country were only ever half pacified by the invaders, while north Wales can lay claim to being the very last part of the Roman Empire to fall to the barbarians-when it fell to the English under Edward I in 1282. It seems that it was in these ‘backward’ parts of the empire that people found it easiest to re-establish tribal structures and effective military resistance.

Sophistication and specialization, characteristic of most of the Roman world, were fine, as long as they worked: Romans bought their pots from professional potters, and bought their defense from professional soldiers. From both they got a quality product–much better than if they had had to do their soldiering and potting themselves. However, when disaster struck and there were no more trained soldiers and no more expert potters around, the general population lacked the skills and structures needed to create alternative military and economic systems. In these circumstances, it was in fact better to be a little ‘backward’.

Unlike the Romans, who relied for their military strength on a professional army (and therefore on tax), freeborn Germanic males looked on fighting as a duty, a mark of status, and, perhaps, even a pleasure. As a result, large numbers of them were practiced in warfare-a very much higher proportion of the population than amongst the Romans. Within reach of the Rhine and Danube frontiers lived tens of thousands of men who had been brought up to think of war as a glorious and manly pursuit, and who had the physique and basic training to put these ideals into practice. Fortunately for the Romans, their innate bellicosity was, however, to a large extent counterbalanced by another, closely related, feature of tribal societies-disunity, caused by fierce feuds, both between tribes and within them.

Already, before the later fourth century, there had been a tendency for the small Germanic tribes of early imperial times to coalesce into larger political and military groupings. But events at the end of this century and the beginning of the next unquestionably accelerated and consolidated the trend. In 376 a disparate and very large number of Goths were forced by the Huns to seek refuge across the Danube and inside the empire. By 378 they had been compelled by Roman hostility to unite into the formidable army that defeated Valens at Adrianopolis. At the very end of 406 substantial numbers of Vandals, Alans, and Sueves crossed the Rhine into Gaul. All these groups entered a still functioning empire, and, therefore, a very hostile environment. In this world, survival depended on staying together in large numbers. Furthermore, invading armies were able to pick up and assimilate other adventurers, ready to seek a better life in the service of a successful war band. We have already met the soldiers of the dead Stilicho and the slaves of Rome, who joined the Goths in Italy in 408; but even as early as 376-8 discontents and fortune-seekers were swelling Gothic ranks, soon after they had crossed into the empire-the historian Ammianus Marcellinus tells us that their numbers were increased significantly, not only by fleeing Gothic slaves, but also by miners escaping the harsh conditions of the state’s gold mines and by people oppressed by the burden of imperial taxation.

The different groups of incomers were never united, and fought each other, sometimes bitterly, as often as they fought the `Romans’– just as the Roman side often gave civil strife priority over warfare against the invaders.” When looked at in detail, the ‘Germanic invasions’ of the fifth century break down into a complex mosaic of different groups, some imperial, some local, and some Germanic, each jockeying for position against or in alliance with the others, with the Germanic groups eventually coming out on top.

Balkans, Italy, Gaul, and Spain between 376 and 419, were indeed quite unlike the systematic annexations of neighboring territory that we expect of a true invasion. These Goths on entering the empire left their homelands for good. They were, according to circumstance (and often concurrently), refugees, immigrants, allies, and conquerors, moving within the heart of an empire that in the early fifth century was still very powerful. Recent historians have been quite correct to emphasize the desire of these Goths to be settled officially and securely by the Roman authorities. What the Goths sought was not the destruction of the empire, but a share of its wealth and a safe home within it, and many of their violent acts began as efforts to persuade the imperial authorities to improve the terms of agreement between them.

The incoming peoples were not ideologically opposed to Rome–they wanted to enjoy a slice of the empire rather than to destroy the whole thing. Emperors and provincials could, and often did, come to agreements with the invaders. For instance, even the Vandals, the traditional ‘bad boys’ of this period, were very happy to negotiate treaty arrangements, once they were in a strong enough negotiating position. Indeed it is a striking but true fact that emperors found it easier to make treaties with invading Germanic armies who would be content with grants of money or land than with rivals in civil wars-who were normally after their heads.

Because the military position of the imperial government in the fifth century was weak, and because the Germanic invaders could be appeased, the Romans on occasion made treaties with particular groups, formally granting them territory on which to settle in return for their alliance.

Is it really likely that Roman provincials were cheered by the arrival on their doorsteps of large numbers of heavily armed barbarians under the command of their own king? To understand these treaties, we need to appreciate the circumstances of the time, and to distinguish between the needs and desires of the local provincials, who actually had to host the settlers, and those of a distant imperial government that made the arrangements. I doubt very much that the inhabitants of the Garonne valley in 419 were happy to have the Visigothic army settled amongst them; but the government in Italy, which was under considerable military and financial pressure, might well have agreed this settlement, as a temporary solution to a number of pressing problems. It bought an important alliance at a time when the imperial finances were in a parlous condition. At the same time it removed a roving and powerful army from the Mediterranean heartlands of the empire, converting it into a settled ally on the fringes of a reduced imperial core. Siting these allies in Aquitaine meant that they could be called upon to fight other invaders, in both Spain and Gaul. They could also help contain the revolt of the Bacaudae, which had recently erupted to the north, in the region of the Loire. It is even possible that the settlement of these Germanic troops was in part a punishment on the aristocracy of Aquitaine, for recent disloyalty to the emperor.

The interests of the center when settling Germanic peoples, and those of the locals who had to live with the arrangements, certainly did not always coincide. The granting to some Alans of lands in northern Gaul in about 442, on the orders of the Roman general Aetius, was resisted in vain by at least some of the local inhabitants. The Alans, to whom lands in northern Gaul had been assigned by the patrician Aetius to be divided with the inhabitants, subdued by force of arms those who resisted, and, ejecting the owners, forcibly took possession of the land. But, from the point of view of Aetius and the imperial government, the same settlement offered several potential advantages. It settled one dangerous group of invaders away from southern Gaul (where Roman power and resources were concentrated); it provided at least the prospect of an available ally; and it cowed the inhabitants of northern Gaul, many of whom had recently been in open revolt against the empire.) All this, as our text makes very clear, cost the locals a very great deal. But the cost to the central government was negligible or non-existent, since it is unlikely that this area of Gaul was any longer providing significant tax revenues or military levies for the emperor. If things went well (which they did not), the settlement of these Alans might even have been a small step along the path of reasserting imperial control in northern Gaul.

The imperial government was entirely capable of selling its provincial subjects downriver, in the interests of short-term political and military gain.

At a number of points along the line, things might have gone differently, and the Roman position might have improved, rather than worsened. Bad luck, or bad judgment, played a very important part in what actually happened. For instance, had the emperor Valens won a stunning victory at Hadrianopolis in 378 (perhaps by waiting for the western reinforcements that were already on their way), the ‘Gothic problem’ might have been solved, and a firm example would have been set to other barbarians beyond the Danube and Rhine. Similarly, had Stilicho in 402 followed up victories in northern Italy over the Goths with their crushing defeat, rather than allowing them to retreat back into the Balkans, it is much less likely that another Germanic group in 405-6, and the Vandals, Alans, and Sueves in 406, would have taken their chances within the western empire.

How did the East Survive? The eastern half of the Roman empire survived the Germanic and Iiunnic attacks of this period, to flourish in the 5th and early 6th centuries; indeed it was only a thousand years later, with the Turkish capture of Constantinople in 1453, that it came to an end. No account of the fall of the western empire can be fully satisfactory if it does not discuss how the East managed to resist very similar external pressure. Here, I believe, it was primarily good fortune, rather than innately greater strength, that was decisive.

The Cost of Peace. The new arrivals demanded and obtained a share of the empire’s capital wealth, which at this date meant primarily land. We know for certain that many of the great landowners of post-Roman times were of Germanic descent, even though we have very little information as to how exactly they had obtained their wealth at the expense of its previous owners.

The Germanic settlers rapidly used their power to acquire more wealth.

The Germanic peoples entered the empire with no ideology that they wished to impose, and found it most advantageous and profitable to work closely, within the well-established and sophisticated structures of Roman life. The Romans as a group unquestionably lost both wealth and power in order to meet the needs of a new, and dominant, Germanic aristocracy. But they did not lose everything, and many individual Romans were able to prosper under the new dispensation.

In the case of the Anglo-Saxons and others who bordered Roman territory by land or sea, the number of immigrants was probably substantially larger, since here the initial conquests could readily he followed up by secondary migration. However, except perhaps in regions that were right on the frontiers, it is unlikely that the numbers involved were so large as to dispossess many at the level of the peasantry. Many smallholders in the new kingdoms probably continued to hold their land much as before, except that much of the tax and rent that they paid will now have gone to enrich Germanic masters.

THE DISAPPEARANCE OF COMFORT

It is currently deeply unfashionable to state that anything like a ‘crisis’ or a ‘decline’ occurred at the end of the Roman empire, let alone that a ‘civilization’ collapsed and a ‘dark age’ ensued. The new orthodoxy is that the Roman world, in both East and West, was slowly, and essentially painlessly,’transformed’ into a medieval form. However, there is an insuperable problem with this new view: it does not fit the mass of archaeological evidence now available, which shows a startling decline in western standards of living during the 5th to 7th centuries. This was a change that affected everyone, from peasants to kings, even the bodies of saints resting in their churches. It was no mere transformation-it was decline on a scale that can reasonably be described as ‘the end of a civilization’.

The Fruits of the Roman Economy

The Romans produced goods, including mundane items, to a very high quality, and in huge quantities; and then spread them widely, through all levels of society. Because so little detailed written evidence survives for these humble aspects of daily, life, it used to be assumed that few goods moved far from home, and that economic complexity in the Roman period was essentially there to satisfy the needs of the state and the whims of the elite, with little impact on the broad mass of society. However, painstaking work by archaeologists has slowly transformed this picture, through the excavation of hundreds of sites, and the systematic documentation and study of the artefacts found on them. This research has revealed a sophisticated world, in which a north-Italian peasant of the Roman period might eat off tableware from the area near Naples, store liquids in an amphora from North Africa, and sleep under a tiled roof. Almost all archaeologists, and most historians, now believe that the Roman economy was characterized, not only by an impressive luxury market, but also by a very substantial middle and lower market for high-quality functional products.

Evidence comes from the study of the different types of pottery found in such abundance on Roman sites: functional kitchen wares, used in the preparation of food; fine table wares, for its presentation and consumption; and amphorae, the large jars used throughout the Mediterranean for the transport and storage of liquids, such as wine and oil.’

Pots, although not normally the heroes of history books, deserve our attention. Three features of Roman pottery are remarkable, and not to be found again for many centuries in the West: its excellent quality and considerable standardization; the massive quantities in which it was produced; and its widespread diffusion, not only geographically (sometimes being transported over many hundreds of miles), but also socially (so that it reached, not just the rich, but also the poor). In the areas of the Roman world that I know best, central and northern Italy, after the end of the Roman world, this level of sophistication is not seen again until perhaps the fourteenth century, some 800 years later.

What strikes the eye and the touch most immediately and most powerfully with Roman pottery is its consistently high quality. This is not just an aesthetic consideration, but also a practical one. These vessels are solid (brittle, but not friable), they are pleasant and easy to handle (being light and smooth), and, with their hard and sometimes glossy surfaces, they hold liquids well and are easy to wash. Furthermore, their regular and standardized shapes will have made them simple to stack and store. When people today are shown a very ordinary Roman pot, and, in particular, are allowed to handle it, they often comment on how ‘modern’ it looks and feels, and need to be convinced of its true age.

On the left bank of the Tiber in Rome, by one of the river ports of the ancient city, is a substantial hill some So meters high, Monte Testaccio, Pottery Mountain, is a reasonable translation into English. It is made up entirely of broken oil amphorae, mainly of the second and third centuries AD and primarily from the province of Baetica in south-western Spain. It has been estimated that Monte Testaccio contains the remains of some 53 million amphorae, in which around 6,000,000,000 liters of oil were imported into the city from overseas.” Imports into imperial Rome were supported by the full might of the state and were therefore quite exceptional-but the size of operations at Monte Testaccio, and the productivity and complexity that lay behind them, none the less cannot fail to impress. This was a society with similarities to our own-moving goods on a gigantic scale, manufacturing high-quality containers to do so, and occasionally, as here, even discarding them on delivery. Like us, the Romans enjoy the dubious distinction of creating a mountain of good-quality rubbish.

In all but the remotest regions of the empire, Roman pottery of a high standard is common on the sites of humble villages and isolated farmsteads.

Pottery in most cultures is vital in relation to one of our primary needs, food. Ceramic vessels, of different shapes and sizes, play an essential part in the storage, preparation, cooking, and consumption of foodstuffs. They certainly did so in Roman times, even more than they do today, since their importance for storage and cooking has declined considerably in modern times, with the invention of cardboard and plastics, and with the spread of cheap metal ware and glass.

Amphorae, not barrels, were the normal containers for the transport and domestic storage of liquids. There is every reason to see pottery vessels as central to the daily life of Roman times.

I am also convinced that the broad picture that we can reconstruct from pottery can reasonably be applied to the wider economy. Pots are low-value, high-bulk items, with the additional disadvantage of being brittle-in other words, no one has ever made a large profit from making a single pot (except for quite exceptional art objects), and they are difficult and expensive to pack and transport, being heavy, bulky, and easy to break. If, despite these disadvantages, vessels (both fine table wares and more functional items) were being made to a high standard and in large quantities, and if they were travelling widely and percolating through even the lower levels of society-as they were in the Roman period-then it is much more likely than not that other goods, whose distribution we cannot document with the same confidence, were doing the same. If good-quality pottery was reaching even peasant households, then the same is almost certainly true of other goods, made of materials that rarely survive in the archaeological record, like cloth, wood, basketwork, leather, and metal. There is, for instance, no reason to suppose that the huge markets in clothing, foot ware, and tools were less sophisticated than that in pottery.

Further confirmation for this view can be found in an even humbler item, which also survives well in the soil but has received less scholarly attention than pottery-the roof tile.

Even buildings intended only for storage or for animals may well often have been tiled:

Tiles can be made locally in much of the Roman world, but they still require a large kiln, a lot of clay, a great deal of fuel, and expertise. After they have been manufactured, carrying them, even over short distances, without the advantages of mechanized transport, is also no mean feat. On many of the sites where they have been found, they can only have arrived laboriously, a few at a time, loaded onto pack animals. The roofs we have been looking at may not seem very important, but they represented a substantial investment in the infrastructure of rural life. A tiled roof may appeal in part because it is thought to be smart and fashionable, but it also has considerable practical advantages over roofs in perishable materials, such as thatch or wooden shingles. Above all, it will last much longer, and, if made of standardized well-fired tiles, as Roman roofs were, will provide more consistent protection from the rain-with minor upkeep, a tiled roof can function well for centuries; whereas even today a professionally laid thatch roof, of straw grown specifically for its durability, will need to be entirely remade every thirty years or so. A tiled roof is also much less likely to catch fire, and to attract insects, than wooden shingles or thatch. In Roman Italy, indeed in parts of pre-Roman Italy, many peasants, and perhaps even some animals, lived under tiled roofs. After the Roman period, sophisticated conditions such as these did not return until quite recent times.

Even smaller industries will have required considerable skills and some specialization in order to flourish, including, for example: the selection and preparation of clays and decorative slips; the making and maintenance of tools and kilns; the primary shaping of the vessels on the wheel; their refinement when half-dry; their decoration; the collection and preparation of fuel; the stacking and firing of the kilns; and the packing of the finished goods for transport. From unworked clay to finished product, a pot will have passed through many different processes and several different hands, each with its own expert role to play.

To reach the consumer then required a network of merchants and traders, and a transport infrastructure of roads, wagons, and pack animals, or sometimes of boats, ships, river- and sea-ports.

How exactly all this worked we will never know, because we have so few written records from the Roman period to document it; but the archaeological testimony of goods spread widely around their region of production, and sometimes further afield, is testimony enough to the fact that complex mechanisms of distribution did exist to link a potter at his kiln with a farmer needing a new bowl to eat from.

Wrecks filled with amphorae are so common that two scholars have recently wondered whether the volume of Mediterranean trade in the second century AD was again matched before the nineteenth century.

I am keen to emphasize that in Roman times good-quality articles were available even to humble consumers, and that production and distribution were complex and sophisticated. In many ways, this is a world like our own; but it is also important to try and be a little more specific. Although this is inevitably a guess, I think we are looking at a world that is roughly comparable, in terms of the range and quality of goods available, to that of the thirteenth to fifteenth centuries, rather than at a mirror image of our own times. The Roman period was not characterized by the consumer frenzy and globalized production of the modern developed world, where mechanized production and transport, and access to cheap labor overseas, have produced mountains of relatively inexpensive goods, often manufactured thousands of miles away. In Roman times machines still played only a relatively small part in manufacture, restricting the quantity of goods that could be made; and everything was transported by humans and animals, or, at best, by the wind and the currents. Consequently, goods imported from a distance were inevitably more expensive and more prestigious than local products.

Although some goods traveled remarkable distances, the majority of consumption was certainly local and regional-Roman pottery, for instance, is always much commoner near its production site than in more distant areas.

Many people were able to buy at least a few of the more expensive products from afar.

However, even if many would now choose to prioritize the role of the merchant over that of the state, no one would want to deny that the impact of state distribution was also considerable. Monte Testaccio alone testifies to a massive state effort with a wide impact: on Spanish olive-growers; on amphora-manufacturers; on shippers; and, of course, on the consumers of Rome itself, who thereby had their supply of olive oil guaranteed. The needs of the imperial capitals, like Rome and Constantinople, and of an army of around half a million men, stationed mainly on the Rhine and Danube and on the frontier with Persia, were very considerable, and the impressive structures that the Roman state set up to supply them are at least partially known from written records.

The distributive activities of the state and of private commerce have sometimes been seen as in conflict with each other; but in at least some circumstances they almost certainly worked together to mutual advantage. For instance, the state coerced and encouraged shipping between Africa and Italy, and built and maintained the great harbor works at Carthage and Ostia, because it needed to feed the city of Rome with huge quantities of African grain. But these grain ships and facilities were also available for commercial and more general use.

The End of Complexity. In the post-Roman West, almost all this material sophistication disappeared. Specialized production and all but the most local distribution became rare, unless for luxury goods; and the impressive range and quantity of high-quality functional goods, which had characterized the Roman period, vanished, or, at the very least, were drastically reduced. The middle and lower markets, which under the Romans had absorbed huge quantities of basic, but good-quality, items, seem to have almost entirely disappeared. Pottery, again, provides us with the fullest picture. In some regions, like the whole of Britain and parts of coastal Spain, all sophistication in the production and trading of pottery seems to have disappeared altogether: only vessels shaped without the use of the wheel were available, without any functional or aesthetic refinement. In Britain, most pottery was not only very basic, but also lamentably friable and impractical. In other areas, such as the north of Italy, some solid wheel-turned pots continued to be made and some soapstone vessels imported, but decorated table wares entirely, or almost entirely, disappeared; and, even amongst kitchen wares, the range of vessels being manufactured was gradually reduced to only a very few basic shapes. By the seventh century, the standard vessel of northern Italy was the olla (a simple bulbous cooking pot), whereas in Roman times this was only one vessel type in an impressive batterie de cuisine (jugs, plates, bowls, serving dishes, mixing and grinding bowls, casseroles, lids, amphorae, and others).

The great tableware producers of Roman North Africa continued to make (and export) their wares throughout the fifth and sixth centuries, and indeed into the latter half of the seventh. But the number of pots exported and their distribution became gradually more-and-more restricted-both geographically (to sites on the coast, and eventually, even there, only to a very few privileged centers like Rome), and socially (so that African pottery, once ubiquitous, by the sixth century is found only in elite settlements).

It was not only quality and diversity that declined; the overall quantities of pottery in circulation also fell dramatically.

Rome continued to import amphorae and table wares from Africa even in the late seventh century, and it was here, in the eighth century, that one of the very first medieval glazed wares was developed. These features are impressive, suggesting the survival within the city of something close to a Roman-style ceramic economy. But, even in this exceptional case, a marked decline from earlier times is evident, if we look at overall quantities.

In the Mediterranean region, the decline in building techniques and quality was not quite so drastic-what we witness here, as with the history of pottery production, is a dramatic shrinkage, rather than a complete disappearance. Domestic housing in post-Roman Italy, whether in town or countryside, seems to have been almost exclusively of perishable materials. Houses, which in the Roman period had been primarily of stone and brick, disappeared, to be replaced by settlements constructed almost entirely of wood. Even the dwellings of the landed aristocracy became much more ephemeral, and far less comfortable: archaeologists, despite considerable efforts, have so far failed to find any continuity into the late-sixth and seventh centuries of the impressive rural and urban houses that had been a ubiquitous feature of the Roman period-with their solid walls, and marble and mosaic floors, and their refinements such as underfloor heating and piped water.

It may have been as much as a thousand years later, perhaps in the fourteenth or fifteenth centuries, that roof tiles again became as readily available and as widely diffused in Italy as they had been in Roman times. In the meantime, the vast majority of the population made do with roofing materials that were impermanent, inflammable, and insect-infested. Furthermore, this change in roofing was not an isolated phenomenon, but symptomatic of a much wider decline in domestic building standards-early medieval flooring, for instance, in all but palaces and churches, seems to have been generally of simple beaten earth.

Coinage is undoubtedly a great facilitator of commercial exchange-copper coins, in particular, for small transactions. In the absence of coinage, raw bullion for major purchases, and barter for minor ones, can admittedly be much more sophisticated than we might initially suppose.” But barter requires two things that coinage can circumvent: the need for both sides to know, at the moment of agreement, exactly what they want from the other party; and, particularly in the case of an exchange that involves one party being ‘paid back’ in the future, a strong degree of trust between those who are doing the exchanging. If I want to exchange one of my cows for a regular supply of eggs over the next five years, I can do this, but only if I trust the chicken-farmer. Barter suits small face-to-face communities, in which trust either already exists between parties, or can be readily enforced through community pressure. But it does not encourage the development of complex economies, where goods and money need to circulate impersonally. In a monied economy, I can exchange my cow for coins, and only later, and perhaps in a distant place, decide when and how to spend them. I need only trust the coins that I receive.

A Return to Prehistory? The economic change that I have outlined was an extraordinary one. What we observe at the end of the Roman world is not a ‘recession’ with an essentially similar economy continuing to work at a reduced pace. Instead what we see is a remarkable qualitative change, with the disappearance of entire industries and commercial networks. The economy of the post-Roman West is not that of the fourth century reduced in scale, but a very different and far less sophisticated entity. This is at its starkest and most obvious in Britain. A number of basic skills disappeared entirely during the fifth century, to be reintroduced only centuries later. Some of these, such as the technique of building in mortared stone or brick,

All over Britain the art of making pottery on a wheel disappeared in the early fifth century, and was not reintroduced for almost 300 years.

Rare elite items, made or imported for the highest levels of society. At this level, beautiful objects were still being made, and traded or gifted across long distances. What had totally disappeared, however, were the good-quality, low-value items, made in hulk, and available so widely in the Roman period.

The complex system of production and distribution, whose disappearance we have been considering, was an older and more deeply rooted phenomenon than an exclusively `Roman’ economy. Rather, it was an ‘ancient’ economy that in the eastern and southern Mediterranean was flourishing long before Rome became at all significant, and that even in the north-western Mediterranean was developing steadily before the centuries of Roman domination. Cities such as Alexandria, Antioch, Naples and Marseille were ancient long before they fell under Roman control.

What was destroyed in the post-Roman centuries, and then only very slowly re-created, was a sophisticated world with very deep roots indeed.

Patterns of Change. There was no single moment, nor even a single century of collapse. The ancient economy disappeared at different times and at varying speeds across the empire.

There is general agreement that Roman Britain’s sophisticated economy disappeared remarkably quickly and remarkably early. There may already have been considerable decline in the later fourth century, but, if so, this was a recession, rather than a complete collapse: new coins were still in widespread use and a number of sophisticated industries still active. In the early fifth century all this disappeared, and, as we have seen in the previous chapter, Britain reverted to a level of economic simplicity similar to that of the Bronze Age, with no coinage, and only hand-shaped pots and wooden buildings.2 Further south, in the provinces of the western Mediterranean, the change was much slower and more gradual, and is consequently difficult to chart in detail. But it would be reasonable to summarize the change in both Italy and North Africa as a slow decline, starting in the fifth century (possibly earlier in Italy), and continuing on a steady downward path into the seventh. Whereas in Britain the low point had already been reached in the fifth century, in Italy and North Africa it probably did not occur until almost two centuries later, at the very end of the sixth century, or even, in the case of Africa, well into the seventh.’ Turning to the eastern Mediterranean, we find a very different story. The best that can be said of any western province after the early fifth century is that some regions continued to exhibit a measure of economic complexity, although always within a broad context of decline. By contrast, throughout almost the whole of the eastern empire, from central Greece to Egypt, the fifth and early sixth centuries were a period of remarkable expansion. We know that settlement not only increased in this period, but was also prosperous, because it left behind a mass of newly built rural houses, often in stone, as well as a rash of churches and monasteries across the landscape (Fig. 6.2). New coins were abundant and widely diffused, and new potteries, supplying distant as well as local markets, developed on the west coast of modern Turkey, in Cyprus, and in Egypt-. Furthermore, new types of amphora appeared, in which the wine and oil of the Levant and of the Aegean were transported both within the region, and outside it, even as far as Britain and the upper Danube. If we measure `Golden Ages’ in terms of material remains, the fifth and sixth centuries were certainly golden for most of the eastern Mediterranean, in many areas leaving archaeological traces that are more numerous and more impressive than those of the earlier Roman empire.’ In the Aegean, this prosperity came to a sudden and very dramatic end in the years around AD 6oo.` Great cities such as Corinth, Athens, Ephesus, and Aphrodisias, which had dominated the region since long before the arrival of the Romans, shrank to a fraction of their former size-the recent excavations at Aphrodisias suggest that the greater part of the city became in the early seventh century an abandoned ghost town, peopled only by its marble statues.” The tablewares and new coins, which had been such a prominent feature of the fifth and sixth centuries, disappeared with a suddenness similar to the experience of Britain some two centuries earlier

My focus here, however, will be on what happened after the invasions began. The evidence available very strongly suggests that political and military difficulties destroyed regional economies, irrespective of whether they were flourishing or already in decline. The death of complexity in Britain in the early fifth century must certainly have been closely related to the withdrawal of Roman power from the province, since the two things happened at more or less at the same time.

All regions, except Egypt and the Levant, suffered from the disintegration of the Roman empire, but distinctions between the precise histories of different areas show that the impact of change varied quite considerably. In Britain in the early fifth century, and in the Aegean world around AD 6oo, collapse seems to have happened suddenly and rapidly, as though caused by a series of devastating blows. But in Italy and Africa change was much more gradual, as if brought about by the slow decline and death of complex systems. These different trajectories make considerable sense. The Aegean was hit by repeated invasion and raiding at the very end of the sixth century, and throughout the seventh-first by Slavs and Avars (in Greece), then by Persians (in Asia Minor), and finally by Arabs (on both land and sea).

The effect of the disintegration of the Roman state cannot have been wholly dissimilar to that caused by the dismemberment of the Soviet command economy after 1989. The Soviet structure was, of course, a far larger, more complex, and all-inclusive machine than the Roman. But most of the former Communist bloc has faced the problems of adjustment to a new world in a context of peace, whereas, for the Romans of the West, the end of the state economy coincided with a prolonged period of invasion and civil war. The emperors also maintained, primarily for their own purposes, much of the infrastructure that facilitated trade: above all a single, abundant, and empire-wide currency; and an impressive network of harbours, bridges, and roads. The Roman state minted coins less for the good of its subjects than to facilitate the process of taxing them; and roads and bridges were repaired mainly in order to speed up the movement of troops and government envoys. But coins in fact passed through the hands of merchants, traders, and ordinary citizens far more often than those of the taxman; and carts and pack animals travelled the roads much more frequently than did the legions.” With the end of the empire, investment in these facilities fell dramatically: in Roman times, for instance, there had been a continuous process of upgrading and repairing the road network, commemorated by the erection of dated milestones; there is no evidence that this continued in any systematic way beyond the early sixth century.

Security was undoubtedly the greatest boon provided by Rome

it is a remarkable fact that few cities of the early empire were walled-a state of affairs not repeated in most of Europe and the Mediterranean until the late nineteenth century, and then only because high explosives had rendered walls ineffective as a form of defense. The security of Roman times provided the ideal conditions for economic growth.

There were also other problems that played a subsidiary role. In 541, for instance, bubonic plague reached the Mediterranean

Economic sophistication has a negative side

Because the ancient economy was in fact a complicated and interlocked system, its very sophistication rendered it fragile and less adaptable to change. For bulk, high-quality production to flourish in the way that it did in Roman times, a very large number of people had to be involved, in more-or-less specialized capacities. First, there had to be the skilled manufacturers, able to make goods to a high standard, and in a sufficient quantity to ensure a low unit-cost. Secondly, a sophisticated network of transport and commerce had to exist, in order to distribute these goods efficiently and widely. Finally, a large (and therefore generally scattered) market of consumers was essential, with cash to spend and an inclination to spend it. Furthermore, all this complexity depended on the labour of the hundreds of other people who oiled the wheels of manufacture and commerce by maintaining an infrastructure of coins, roads, boats, wagons, wayside hostelries, and so on. Economic complexity made mass-produced goods available, but it also made people dependent on specialists or semi-specialists-sometimes working hundreds of miles away-for many of their material needs. This worked very well in stable times, but it rendered consumers extremely vulnerable if for any reason the networks of production and distribution were disrupted, or if they themselves could no longer afford to purchase from a specialist. If specialized production failed, it was not possible to fall back immediately on effective self-help. Comparison with the contemporary western world is obvious and important. Admittedly, the ancient economy was nowhere near as intricate as that of the developed world in the twenty-first century. We sit in tiny productive pigeon-holes, making our minute and highly specialized contributions to the global economy and we are wholly dependent for our needs on thousands, indeed hundreds of thousands, of other people spread around the globe, each doing their own little thing. We would be quite incapable of meeting our needs locally, even in an emergency. The ancient world had not come as far down the road of specialization and helplessness as we have.

The enormity of the economic disintegration that occurred at the end of the empire was almost certainly a direct result of this specialization. The post-Roman world reverted to levels of economic simplicity, lower even than those of immediately pre-Roman times, with little movement of goods, poor housing, and only the most basic manufactured items.

The sophistication of the Roman period, by spreading high-quality goods widely in society, had destroyed the local skills and local networks that, in pre-Roman times, had provided lower-level economic complexity. It took centuries for people in the former empire to reacquire the skills and the regional networks that would take them back to these pre-Roman levels of sophistication.

Food production may also have slumped, causing a steep drop in the population. Almost without exception, archaeological surveys in the West have found far fewer rural sites of the fifth, sixth, and seventh centuries AD than of the early empire.  In many cases, the apparent decline is startling, from a Roman landscape that was densely settled and cultivated, to a post-Roman world that appears only very sparsely inhabited. Almost all the dots that represent Roman-period settlements disappear, leaving only large empty spaces. At roughly the same time, evidence for occupation in towns also decreases dramatically-the fall in the number of rural settlements was certainly not produced by a flight from the countryside into the cities.

Since economic complexity definitely increased the quality and quantity of manufactured goods, it is more likely than not that it also increased production of food, and therefore the number of people the land could feed. Archaeological evidence, from periods of prosperity, does indeed seem to show a correlation between increasing sophistication in production and marketing, and a rising population.

However sophisticated Roman agriculture was, harvests could still fail, and, when they did, transport was not cheap or rapid enough to bring in the large quantities of affordable grain that could have saved the poor from starvation. Edessa in Mesopotamia was one of the richest cities of the Roman East, surrounded by prosperous arable farming. But in AD 500 a swarm of locusts consumed the wheat harvest; a later harvest, of millet, also failed. For the poor, disaster followed. The price of bread shot up, and people were forced to sell their few possessions for a pittance in order to buy food. Many tried, in vain, to assuage their hunger with leaves and roots. Those who could, fled the region; but crowds of starving people flocked into Edessa and other cities, to sleep rough and to beg: ‘They slept in the colonnades and streets, howling night and day from the pangs of hunger.’ Here disease and the cold nights of winter killed large numbers of them; even collecting and burying the dead became a major problem.”‘

If we ask ourselves how the ability to read and write came to be so widespread in the Roman world, the answer probably lies in a number of different developments, which all encouraged the use of writing. In particular, there is no doubt that the complex mechanism of the Roman state required literate officials at all levels of its operations. There was no other way that the state could raise taxes in coin or kind from its provincials, assemble the resulting profits, ship them across long distances, and consume or spend them where they were needed. A great many lists and tallies will have been needed to ensure that a gold solidus raised in one of the peaceful provinces of the empire, like Egypt or Africa, was then spent effectively to support a soldier on the distant frontiers of Mesopotamia, the Danube, or the Rhine.

In Italy, the primacy of ancient civilization is seldom doubted, and a traditional view of the end of the Roman world is very much alive. Most Italians are with me in remaining highly skeptical about a peaceful `accommodation’ of the barbarians, and the ‘transformation’ of the Roman world into something new and equally sophisticated.’ The idea that the Germanic incomers were peaceful immigrants, who did no harm, has not caught on.

[ My comment: Egads! American historians are so politically correct that they ignore the role of invading immigrants and material life ]

A recent Guide to Late Antiquity, published by Harvard University Press, asks us “to treat the period between around 250 and 800 as a distinctive and quite decisive period of history that stands on its own’, rather than as the story of the unraveling of a once glorious and “higher” state of civilization”. This is a bold challenge to the conventional view of darkening skies and gathering gloom as the empire dissolved.

Words like ‘decline’ and ‘crisis’, which suggest problems at the end of the empire and which were quite usual into the 1970s, have largely disappeared from historians’ vocabularies, to be replaced by neutral terms, like ‘transition’, ‘change’, and ‘transformation’.

Here too old certainties are being challenged. According to the traditional account, the West was, quite simply, overrun by hostile ‘waves’ of Germanic peoples. The long-term effects of these invasions have, admittedly, been presented in very different ways, depending largely on the individual historian’s nationality and perspective. For some, particularly in the Latin countries of Europe, the invasions were entirely destructive. For others, however, they brought an infusion of new and freedom-loving Germanic blood into a decadent empire.

Unsurprisingly, an image of violent and destructive Germanic invasion was very much alive in continental Europe in the years that immediately followed the Second World War.” But in the latter half of the twentieth century, as a new and peaceful Western Europe became established, views of the invaders gradually softened and became more positive

More recently, however, some historians have gone very much further than this, notably the Canadian historian Walter Goffart, who in 1980 launched a challenge to the very idea of fifth-century ‘invasions’. He argued that the Germanic peoples were the beneficiaries of a change in Roman military policy. Instead of continuing the endless struggle to keep them out, the Romans decided to accommodate them into the empire by an ingenious and effective arrangement. The newcomers were granted a proportion of the tax revenues of the Roman state, and the right to settle within the imperial frontiers; in exchange, they ceased their attacks, and diverted their energies into upholding Roman power, of which they were now stakeholders. In effect, they became the Roman defense force.

Goffart was very well aware that sometimes Romans and Germanic newcomers were straightforwardly at war, but he argued that ‘the 5th century was less momentous for invasions than for the incorporation of barbarian protectors into the fabric of the West’. In a memorable sound bite, he summed up his argument: “what we call the Fall of the Western Roman empire was an imaginative experiment that got a little out of hand.” Rome did fall, but only because it had voluntarily delegated away its own power, not because it had been successfully invaded. Like the new and positive ‘Late Antiquity’, the idea that the Germanic invasions were in fact a peaceful accommodation has had a mixed reception. The world at large has seemingly remained content with a dramatic ‘Fall of the Roman empire’, played out as a violent and brutal struggle between invaders and invaded.

As someone who is convinced that the coming of the Germanic peoples was very unpleasant for the Roman population, and that the long-term effects of the dissolution of the empire were dramatic, I feel obliged to challenge such views.

The historians who have argued for a new and rosy Late Antiquity are primarily North Americans, or Europeans based in the USA, and they have shifted their focus right out of the western Roman empire. Much of the evidence that sustains the new and upbeat Late Antiquity is rooted firmly in the eastern Mediterranean, where, as we have seen, there is good evidence for prosperity through the fifth and sixth centuries, and indeed into the eighth in the Levant.

Until fairly recently it was institutional, military, and economic history that dominated historians’ views of the fourth to seventh centuries.’ Quite the reverse is now the case, at least in the USA. Of the 36 volumes so far published by the University of California Press in a series entitled ‘The Transformation of the Classical Heritage’, 30 discuss the world of the mind and spirit (primarily different aspects of Christian thought and practice); only five or six cover more secular topics (such as politics and administration); and none focuses on the details of material life.’

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EROI of Canadian Natural Gas. A peak was reached despite enormous investment

[ Although I’ve extracted much of this paper, it is not complete—there are missing equations, figures, tables, and text– so see the paper for details (it is available online).  I’ve rearranged the order of the paper.  The conclusion is just below the introduction.  Some of the important points include:

  1. Natural gas production in Western Canada peaked in 2001 and remained nearly flat until 2006 despite more than quadrupling the drilling rate.
  2. Canada seems to be one of many counter examples to the idea that oil and gas production can rise with sufficient investment.
  3. The drilling intensity for natural gas was so high that net energy delivered to society peaked in 2000–2002, while production did not peak until 2006.
  4. The industry consumed all the extra energy it delivered to maintain the high drilling effort.
  5. The inability of a region to increase net energy may be the best definition of peak production. This increase in energy consumption reduces the total energy provided to society and acts as a contracting pressure on the overall economy as the industry consumes greater quantities of labor, steel, concrete and fuel.
  6. It is clear that state of the art conventional oil & natural gas extraction is unable to improve drilling efficiency as fast as depletion is reducing well quality.
  7. This pattern shows the falsehood of the idea that additional investment always results in increased production. During the initial rising EROI phase, flat or falling drilling rates can increase production, and during the falling EROI phase, production can fall despite dramatic increases in investment.
  8. There appears to be a maximum energy investment that can be sustained, which is about 15:1 to 22:1 EROI or 5% to 7% of gross energy. [If this is the case], then economic growth may not be possible if more energy is diverted into the energy producing sector. If this minimum exists, then it places a lower bound EROI on any energy source that is expected to become a major component of societies’ future energy mix.

Alice Friedemann   www.energyskeptic.com  author of “When Trucks Stop Running: Energy and the Future of Transportation, 2015, Springer]

Freise, J. November 3, 2011 The EROI of Conventional Canadian Natural Gas Production.  Sustainability 2011, 3, 2080-2104.

Abstract: Canada was the world’s third largest natural gas producer in 2008, with 98% of its gas being produced by conventional, tight gas, and coal bed methane wells in Western Canada.

Natural gas production in Western Canada peaked in 2001 and remained nearly flat until 2006 despite more than quadrupling the drilling rate.

Canada seems to be one of many counter examples to the idea that oil and gas production can rise with sufficient investment.

This study calculated the Energy Return on Energy Invested and Net Energy of conventional natural gas and oil production in Western Canada by a variety of methods to explore the energy dynamics of the peaking process. All these methods show a downward trend in EROI during the last decade.

Natural gas EROI fell from 38:1 in 1993 to 15:1 at the peak of drilling in 2005.

The drilling intensity for natural gas was so high that net energy delivered to society peaked in 2000–2002, while production did not peak until 2006.

The industry consumed all the extra energy it delivered to maintain the high drilling effort. The inability of a region to increase net energy may be the best definition of peak production. This increase in energy consumption reduces the total energy provided to society and acts as a contracting pressure on the overall economy as the industry consumes greater quantities of labor, steel, concrete and fuel. It appears that energy production from conventional oil and gas in Western Canada has peaked and entered permanent decline.

Introduction

At the start of the 21st century we have a lot of pressing questions about our future energy supply: Can the world maintain its oil production plateau? Can natural gas production grow to replace coal and oil? Is it physically possible to grow the economy using renewable energy sources or even transition to renewable energy sources? What ties these questions together is a concept called net energy. It takes an investment of energy (in the form of fuel, steel, labor, and more) to produce energy. The net energy is the amount of surplus after this investment has been paid. This surplus is the energy available to operate the rest of the economy. All of these questions may be asked in a simpler form: Can we do X and still maintain or grow the net energy supply? Thus, insight gained from understanding the energy production of fossil fuels may transition to understanding of the growth (or decline) of renewable energy sources.

Canada’s oil and natural gas industry makes an interesting case study for net energy analysis. The country is a very large petroleum producer and was the world’s third largest natural gas producer in 2008 [1] and most of that production comes from the onshore Western Canadian Sedimentary Basin (WCSB). It went through a peak in oil production in the 1970s and, despite an increase in drilling, the country could not return to peak rates. Most recently, natural gas production fell from an eight-year plateau despite a 300% increase in the rate of drilling and an even greater increase in investment.

A net energy analysis of Canadian conventional oil and natural gas provides several things: First, it is a measurement of current conditions. How much net energy is being produced now and what is the trend? Second, it provides insight into the net energy dynamics of the production growth, peak/plateau, and decline for oil and natural gas production. Third, it gives some indication of what net energy levels are needed for an energy system to grow and below which levels cause a peak or decline in the energy system.

Net Energy and the Economy.  It takes energy to produce energy. For natural gas and oil production, energy is consumed as fuel to drive drilling rigs and other vehicles, energy to make the steel in drill and casing pipe, energy to heat the homes of the workers and provide them with food. These energy expenditures make up the cost of producing energy. Net energy is the surplus energy after these costs have been paid.

Friese 2011 NG EROI figure 1

Figure 1. (a) Energy return on energy invested (EROI) 20:1 energy supply & surplus; (b) contraction caused by fall to 10:1 EROI; and (c) Surplus returned by higher end use efficiency.

As costs rise, the energy sector makes a huge increase in its demand for labor, steel, fuel, etc. from society at large, shown by a large increase in the red area. But at the same time, the energy sector is providing no additional energy that is needed to create that extra steel, supply the fuel, or support the labor. Society must then cannibalize other sectors to supply the demands of the energy sector and the non-energy economy is seen to contract. This non-energy sector contraction would then cause a collapse in demand for energy, and returning society to somewhere between A and B.

To help formalize this example, assume Figure 1 shows a theoretical energy source supplying 1 Giga Joule (GJ) of energy. The three columns show three different net energy conditions. Column A shows an energy supply that requires 5% of the gross energy as input energy. It has an EROI of 20:1 and a net energy of 95%. Column B shows the same energy source, but where the cost of producing energy has doubled to consume 10% of the gross energy supply. It has an EROI of 10:1 and a net energy of 90%. The transport, refining, and end use efficiency remain the same and so the final surplus has contracted.

Column C represents a society that has adapted to the lower EROI energy source by improving efficiency of use and the surplus has returned. The more efficient a society, the lower the net energy supply it may subsist upon. This last point will be important when examining the difference between the peaks in oil and natural gas.

CONCLUSION: The Current State of Western Canadian Natural Gas and Oil Production.  All of three methods show a downward trend in EROI during the last decade (Figure 10) and the combined oil and gas industry has fallen from a long term high EROI of 79:1 (about 1% energy consumed) to a low of 15:1 (7% energy consumed)

Friese 2011 Figure 10 EROI comparison according to technique

Figure 10. EROI comparison according to technique.

Natural gas EROI reached an even deeper low of 14:1 (7%) or even 13:1 (8%) with the NEB EUR method.

 

It is clear that state of the art conventional oil & natural gas extraction is unable to improve drilling efficiency as fast as depletion is reducing well quality. The fact that EROI does not rebound to match prior drilling rates and the EUR result shows no rebound indicates that well quality continues to decline. The small rebound in EROI is an result of the rolling average technique of methods one and two.

The conventional oil and gas in the WCSB has peaked. Falling well quality will likely continue to push cost up or production down.

This pattern shows the falsehood of the idea that additional investment always results in increased production. During the initial rising EROI phase, flat or falling drilling rates can increase production, and during the falling EROI phase, production can fall despite dramatic increases in investment.

There appears to be a maximum energy investment that can be sustained, which is about 15:1 to 22:1 EROI or 5% to 7% of gross energy. This might indicate a minimum EROI that can be supported while the economy grows. The minimum was higher for the oil peak than the natural gas peak and this might have been caused by inexpensive imported oil or because the economy had become more energy efficient (Figure 1 column C) allowing a lower minimum EROI.

The natural gas and oil peaks differed when analyzed using net energy. The oil peak had a peak in gross and net energy on the same year, suggesting that some outside factor was responsible for reducing investment. Natural gas showed a net energy peak before a gross production peak. This suggests that price was not the limiting factor in reducing drilling effort. Instead, from 1996 to 2005, the drilling rate for natural gas quadrupled and expenditures rose even faster, despite falling net energy and this in turn suggests that it was falling net energy was the eventual cause of economic contraction and falling prices.

A peak in net energy may be the best definition of “peak” production. When net energy peaks before gross energy it indicates that price was not the limiting factor in the effort to liberate energy. This is a likely model of world net energy production where less expensive imported energy sources cannot replace existing but declining energy sources.

A rise in EROI appears to be possible only when a new resource or region is being exploited, such as the transition from oil to gas as the primary energy production in the WCSB during the late 1980s. This study has focused on conventional natural gas production and it is very uncertain how exploitation of shale gas reserves will change the energy return.

Wider Implications.  Some wider conclusions about renewable energy are suggested by this net energy study. If there is a maximum level of investment between 5% and 7% of gross energy, then economic growth may not be possible if more energy is diverted into the energy producing sector. If this minimum exists then it places a lower bound EROI on any energy source that is expected to become a major component of societies’ future energy mix. For instance, nuclear power with its low EROI is likely below this level [25,26].

Also, if the maximum level of investment is 7% of output energy consumed and a renewable energy source has an EROI of 20:1, or 5%, then the 2% remaining is the maximum that may be invested into growth of the energy source without causing the economy to decline. This radically reduces the rate at which society may change the energy mix that supports it [27].

This study does not attempt to estimate the EROI or net energy of shale gas, but some caution is warranted by comparison between these results and some cursory findings for the cost of shale gas. The International Energy Agency’s World Energy Outlook 2009 contained a graph showing the cost of natural gas production in the Barnett Shale (Figure 11). The core (best) counties, Johnson and Tarrant, show the lowest cost while counties outside the core production region show higher costs.

A very rough comparison can be made to the costs in this report. If the royalty amounts are subtracted and inflation adjusted into $2002 values, the Johnson County cost would be $2.94 resulting in an EROI of roughly 15:1 (7% of output consumed). This is not much higher than the lowest EROI values found in the WCSB. All the remaining Barnett Shale costs are much higher. Hill and Hood would have an EROI of 8:1 and Jack and Erath would have an EROI of roughly 5:1 (22% of output energy consumed in extraction). Given the history of the WCSB production peaks, it is hard to see how shale gas production could be much increased with such low net energy values. Shale gas may have a very short lived EROI increase over conventional while the core counties are exploited and then suffer a production collapse as EROI falls rapidly. This would fit the pattern seen with oil and then with natural gas in the WCSB.

The IEA WEO 2009 also contains Figure 12, an illustration of a world view that increasing cost will liberate more and more energy for use by society.

Friese 2011 figure 12 net energy reduces volume as quality declines

Figure 12. Modified from the IEA WEO 2009 [28] with dotted lines added to illustrate concept of net energy reducing the total volume of energy available as resource quality declines.

 

Conventional gas reservoirs, now peaked in production and shrinking in the WCSB, are seen as the small tip of a huge number of other resources that could be liberated with increasing investment. But falling net energy may prove this view false. If the energy return is too low, production growth may be limited or impossible from many of these energy sources. Much of the energy produced may need to be consumed during extraction. The proper shape of this diagram is likely to be a diamond with non-conventional resources forming a smaller part of the diamond underneath as denoted by the added dotted lines.

 

 

Background on the Western Canadian Sedimentary Basin.  Western Canada produced 98% of Canada’s natural gas in 2009 with the majority of that coming from the Western Canadian Sedimentary Basin (WCSB) that underlies most of Alberta, parts of British Columbia, Saskatchewan and the Northwest Territories [7].

Friese 2011 Energy Content of Petroleum Production by type stacked

Figure 3. Energy Content of Petroleum Production, by type, stacked.

This paper focuses on conventional natural gas, tight natural gas (gas in a low porosity geologic formation that must be liberated via artificial fracturing) and conventional oil production. Western Canadian natural gas production is still largely conventional and so makes a good area of study. In 2008, 55% of marketed natural gas was conventional gas from gas wells, 32% was tight gas, 8% was solution gas from oil wells, 5% coal bed methane (non-conventional), and less than 1% was shale gas [9,10]. Figure 3. Energy Content of Petroleum Production, by type, stacked.

The Canadian Gas Potential Committee in 2005 estimated that the WCSB contains 71% of the conventional gas endowment of Canada and that of an original 278 Tcf of marketable natural gas (technically and economically recoverable) 143 Tcf remain [11]. They note: “The majority of the large gas pools have been discovered and a significant portion of the discovered reserves has been produced” and further “62% of the undiscovered potential occurs in 21,100 pools larger than 1 Bcf OGIP. The remaining 38% of the undiscovered potential occurs in approximately 470,000 pools each containing less than 1 Bcf”. To put this in context, the petroleum industry has drilled less than 200,000 natural gas wells from 1947 to 2009 [7], and so will require at least a doubling of drilling effort to reach at last half of the marketable natural gas.

Results and Discussion.

Method One: EROI and Net Energy of Western Canadian Oil and Gas Production

The Canadian Association of Petroleum Producers (CAPP) maintains records of oil and gas production and expenditures going back to 1947. In theory it is simple to calculate net energy and EROI from this public data. Energy output equals the total production volumes of each hydrocarbon produced in a given year (conventional oil, natural gas, natural gas liquids), which is converted to heat energy equivalents, and measured in Giga Joules. The energy input side is more difficult as the public data for expenditures is recorded only in Canadian $ per year and not in energy. An energy intensity factor is used to convert the dollar expenditures into energy. This factor is calculated from Energy Input Output—Life Cycle Analysis

As the energy intensity factor includes wages paid to labor, but energy inputs are not quality corrected, the results are equivalent to EROIsociety and not the EROIStandard [12]. EROIStandard corrects the input energy for quality but excludes labor costs. The energy intensity factor was 24 MJ/$(U.S. 2002) and all expenditures were inflation corrected and converted to U.S. dollars. While the focus of this paper is on natural gas production, this result provides a historical time line to compare with the more limited time series for natural gas only. The results are first plotted as gross energy and net energy alongside the meters drilled per year as in Figure 4.

Friese 2011 Net energy content ofoil and gas

Figure 4. Net Energy content of oil and gas produced after invested energy is subtracted, with total meters drilled.

The time period from 1947 to 1956 showed rising production along with a rising drilling rate. From 1956 to 1973 production rose despite no corresponding rise in drilling. From 1973 to 1985 production fell despite a rise in drilling effort. The increased drilling rates were unable to increase gross energy and actually drove down net energy during this period.

In the mid-1980s, energy production once again rose with a falling drilling rate. That trend reversed to rising production with increased drilling. Then, in the year 2000, the petroleum industry showed an initial peak in gross and net energy (see Table 1). The increases in drilling effort that happened after 2000 were unable to increase production and actually drove down net energy (falling EROI). When the drilling rate increased, it drove down net energy. When the drilling rate slowed (as it did after 2006) then production dropped and net energy fell even faster.

Friese 2011 table 1 annual gross and net energy prd of oil gas ngl

Table 1. Annual gross and net energy production of oil, gas, and natural gas liquids.

 

Plotting the same data as EROI is quite illuminating. Figure 5 shows that the industry underwent a dramatic rise in energy efficiency from the early 1950s until 1973 when it reached a peak in EROI of 79:1. At this peak the industry consumed only the equivalent of 1% of the energy it produced. Then, the industry suffered a tremendous efficiency drop to a low EROI of 22:1 (about 5% of energy production consumed by investment) only 7 years later as the industry more than doubled its drilling rate in an effort to return to the oil production peak.

Another interesting inflection point was 1985 when the industry started a 7-year period when a reduced drilling rate providing an increase in production. We can see this corresponded to an increase in efficiency as the industry focused on growing natural gas production (see Figure 3). EROI rose to 46:1 (about 2% consumed by investment) by 1992. This fortunate trend was not long lived. Once the drilling rate started to rise, EROI has had a volatile but downward trend to a new low of 15:1 in 2006, where the industry consumed the equivalent of 7% of all the energy it produced. And further, it took a dramatic reduction in drilling and falling back on the production of older wells to achieve the small uptick in EROI seen in 2009.

Friese 2011 EROI of oil and gas 1947-2009

Figure 5. EROI of oil and gas from 1947 to 2009 with meters drilled.

Natural gas from conventional and tight natural gas wells is now the dominant energy source in the WCSB and has just recently peaked. By removing the oil from the net energy and EROI calculations we can gain an insight into the energy dynamics of peak natural gas production. The data necessary to separate oil and gas production and expenditure is limited to 1993 to 2009. The details of splitting out both gas expenditures and gas production from the oil data are explained in Section 3 methodology. The basic method for finding the net energy from natural gas wells alone is very similar to that for oil and natural gas combined. On the energy output side, the difficulty is that oil wells also produce natural gas and NGL and the amount from oil vs. gas wells is not recorded in the CAPP statistics. A NEB report [13] did report the amount of oil well-associated gas for a limited time series and this relation was used to estimate the amount of associated gas for the remaining years. On the input side, the expenditures for oil and gas well drilling and production are also intermixed. As drilling is the largest expense, it was assumed that the distance of drilling is directly proportional to percentage of expenditures. For example, if gas wells were 75% of the meters drilled, then 75% of exploration and development costs were apportioned to natural gas production.

Figure 6 shows the resulting EROI for natural gas wells and displays a variable but downward trend in EROI over the whole data period except for a rebound during 2007 to 2009 when drilling rates fell back to 1998 levels. However, the EROI did not return to 1998 levels along with the drilling rate.

Friese 2011 EROI of natural gas wells

Figure 6. EROI of natural gas wells with meters drilled

Table 2 displays the net energy of natural gas well production. The peak for the estimated gross energy from natural gas wells occurred in 2006 at 6.9 e9 GJ, but the peak in net energy happened much sooner. In 2002, net energy peaked at 6.5 GJ. The drilling industry doubled the meters drilled from 2002 to 2005, but could not deliver more net energy to society. The additional industry investment consumed all the extra energy produced, and more.

Friese 2011 Table 2a

 

 

 

 

 

Friese 2011 Table 2bTable 2. Gross and net energy from natural gas wells. Gross Net Industry Gas Year Energy Energy Directed

The first two methods used to estimate EROI suffer an inherent inaccuracy: The output energy of a given year is mostly produced by wells drilled in past years. Figure 7 shows an example of how production from wells drilled each year stack on top of each other to yield the annual production rate. Each colored band represents the natural gas produced from a given year’s wells. The wells drilled from 2003 to 2004 produced the yellow band. It is easy to see from this chart how most of the natural gas produced in 2003 was actually from wells drilled in prior years.

Friese 2011 Figure 7 estimate of NG prd by wells each year

 

Figure 7. Canadian National Energy Board (NEB) Estimate of natural gas produced by wells drilled each year. From [8].

 

A well may produce oil or gas for 30 years, but all the expense is applied during the year it was drilled. This mismatch in time scales can cause EROI to spike and dip if the drilling rate moves up and down. A rapid increase in drilling can cause EROI to dip as the investment is booked all at once, but production will take years to arrive. A rapid decrease in drilling will cause investment to suddenly drop, while production from wells from previous years stays high and will result in an EROI spike. These spikes and dips are exactly how the economy experiences the change in energy flows, and so it is perfectly valid to use this technique, but the averaging effect hides how the newest wells are performing.

One method to reveal current well performance would be to attribute the expected full life production of the well, the Estimated Ultimate Recovery (EUR), against the investment amount the year the well was drilled. The Canadian National Energy Board does periodic studies of producing natural gas. They calculate the EUR for the wells drilled each year [8]. They examined the wells drilled each year, totaled the past production from those wells, and used decline curves to estimate the remaining production of each year’s wells.

In this third method, the NEB calculated EUR was used instead of the annual production statistics for that year. The goal was to try to estimate the EROI of the very latest natural gas wells drilled and thus learn if the natural gas EROI rebound seen with the rolling average method was an artifact of the drop in drilling rate or if the natural gas wells improved in quality. The results are shown in Tables 3 and 4 and Figure 8. Again, the EROI trend is clearly declining. A specific example is to compare 1997 to 2005. Both years have very similar estimated ultimate recovery (EUR), but 2005 had a capital expenditure that was 3 times higher. This strongly suggests that the well prospects worsened over a short time period.

Friese 2011 table 3

Table 3. Estimated Ultimate Recovery (EUR) and cost per GJ for natural gas wells. Estimated

 

 

 

 

Friese 2011 Table 4Table 4. Total cost per GJ, Net EUR and EROI for natural gas wells.

 

 

 

 

 

 

Friese 2011 figure 8 EROI usnig NEB ests of ultimate recoveryFigure 8. EROI using NEB estimates of ultimate recovery, with meters drilled.

 

The EROI curve in Figure 8 is slightly less volatile than the rolling average technique, but more strikingly, the years 2007 and 2008 do not show the rebound in EROI that the rolling average method displayed. Assuming the NEB estimates for EUR are correct, this result indicates that the rebound was an artifact of the rapidly falling drilling rate on the rolling average and that new wells are performing considerably worse than prior years’ wells.

EROI Boundary

There are many stages to petroleum production: exploration, drilling, gathering and separation, refining, and transport of finished products, and the burning of the final fuel. The EROI could be calculated at any of these points in the process. Some studies have looked at the EROI of these various stages [6]. This paper examines the EROI within a boundary that includes the exploration, drilling, gathering and separating stages. This is typically referred to as the upstream petroleum industry.  This analysis does not include refining, the transport of finished products, or the final usage efficiency. This boundary does include labor costs. These results correspond to EROI society (lower case) as described in the EROI protocol [12].

These results are not quite EROI Standard which would include quality correcting the input energy values (not available from the EIO-LCA) and excluding the labor costs (which are rolled into the industry statistics and not removable). Care should be taken to match the boundary conditions before comparing these results to other studies.

Method One: EROI and Net Energy of Western Canadian Conventional Oil and Gas Production.  The Canadian Association of Petroleum Producers (CAPP) maintains statistics on oil and natural gas production and oil and gas expenditures going back to 1947 [22] but the expense data is intermingled. This forces us to estimate the EROI of oil and gas together, but doing so provides a historical perspective for the more limited natural gas EROI that will be calculated later. The net energy and EROI of the combined oil and natural gas industry is thus the first result calculated.

Energy Output: Oil and Gas Production Statistics. Records of petroleum production are also maintained by CAPP and published in the annual statistical handbook [22]. Summed were the values for Western Canadian conventional oil, marketed natural gas, condensates, ethane, butane, propane, and pentane plus. This paper focuses on conventional production and excludes synthetic oil from tar sands and bitumen production. States included in Western Canada are Alberta, British Columbia, Manitoba, Saskatchewan, and the Northwest Territories. The resulting energy production values are displayed in Figure 3.

Energy Input: Oil and Gas Expenditure Statistics. CAPP also maintains expenditure statistics for the petroleum industry back to 1947 [22]. Statistics are organized by state and major category. Money paid for land acquisition and royalties were excluded as these do not involve energy expenditure (money paid for land and royalties shifts to who gets to spend the industry profits, not how much energy is expended in extracting the resources). Investment categories include these Exploration expenses: Geological and Geophysical, Drilling and Other. Development expenses include: Drilling, Field Equipment, Enhanced Recovery (EOR), Gas Plants, and Other. Operating expenses include: Well and flow lines, Gas Plants and Other. All expenditures from all categories and states were summed into one value for each year.

Inflation Adjustment & Exchange Rate. The Canadian dollar expenditure statistics are nominal must be inflation corrected to the year 2002 to use the energy intensity factor calculated via EIO-LCA analysis. The inflation adjustment is intended to remove the effect of currency devaluation. The inflation adjustment was done using the Canadian CPI [23]. The adjusted results were converted into U.S. $ using the Bank of Canada Annual Average of Exchange rates for 2002 of $1.0 (U.S.) to $1.57 (Canadian) [24] and then converted into Joules of energy input using the expenditures energy intensity factor of 24 MJ/(U.S. 2002).

Combined Oil and Gas Results and Example. The results are displayed in Table 1 located in Section 2.1. A worked example for the year 2002 has an invested energy of 361 e6 GJ = $15 e9 × 24 MJ/($U.S. 2002). Net energy is 9.78 e9 GJ = 10.14 e9 GJ – 0.361 e9 GJ (note the scale change of 361). EROI is 28 = 10.14 e9 GJ / 0.361 e9 GJ.

Method Two: Net Energy and EROI of Western Canadian Natural Gas Wells. The method of calculating the EROI and net energy of natural gas wells is very similar to that used for oil and gas combined. Production and expenditure data were taken from the CAPP statistics and converted to units of energy. Oil production and expenditures were removed (as detailed below). The same energy intensity factor, inflation correction, and exchange rate were used as during the petroleum EROI calculation. The same EROI boundary was used, which includes the gas plants, but not refining or transportation.

Natural Gas Production Statistics. The energy from oil production was excluded, but natural gas also produced as a byproduct of oil production was included. Natural gas is trapped in solution in the liquid oil. The gas comes out of solution when the pressure drops as the oil is produced. Oil also contains some of the lighter fraction hydrocarbons, such as condensates, propane etc. The CAPP statistical handbook does not make the distinction between solution gas and non-associated gas. However, the Canadian National Energy Board provided solution gas data from private sources for the years 2000 to 2008 [13]. Solution gas accounts for about 10% of the total marketed natural gas so it is important it be removed. For 2000 to 2008 the NEB values were used directly. To extend the solution gas estimates for the whole period of 1993 to 2009, a regression was fit between conventional oil production and the amount of solution gas for the 8 years of data. The linear correlation was high, R = 0.93 and the resulting regression was used to predict the amount of solution gas from conventional oil production for the remaining years. The energy in the lighter hydrocarbons (natural gas liquids) needed to be apportioned between oil and gas wells as they are roughly equal to 16% of the energy in the produced natural gas (so about 1.6% of natural gas well gross energy). No public data could be found that suggested a proper ratio, so for this study it was assumed that the ratio of lighter hydrocarbons associated with oil would be the same as the ratio of natural gas associated with the oil. The solution gas ratio was used for each year and that portion of the total NGLs was removed from the gross energy produced.

Natural Gas Exploration and Development Expenditures. The CAPP expenditure statistics encompass both oil and gas expenditures, so some secondary statistic is needed to estimate how the combined expenditures should be apportioned. The statistics do separate the meters of exploration and development drilling that target oil vs. gas wells. For this study it was assumed that the apportionment of expenditure dollars would be directly related to the meters of drilling. This assumption is true only if the oil and gas wells have similar costs. As most oil and gas are produced from the same basin, this was assumed to be a reasonable apportionment (as opposed to if all the natural gas were on shore and the oil production was done much more expensively off shore). The online version of the CAPP statistical handbook contains only the drilling distance statistics for the current year. Copies of data from past handbooks must be requested directly from CAPP for the years 1993 to 2010 [22]. Table 6 relates these hard to acquire numbers. As an example, in 2002 the total meters drilled for oil was 0.71 e6 + 4.65 e6 = 5.36 e6 meters and the total meters drilled for natural gas was 2.63 e6 + 6.02 e6 = 8.65 e6. Natural gas was thus 61.7% of total drilling and so 61.7% of exploration and development expenditures would be apportioned to natural gas wells for 2002. Exactly like the combined oil and gas method, royalties and land expenditures were removed.

References and Notes

  1. International Energy Statistics: Natural Gas Production. http://www.eia.gov/cfapps/ipdbproject/ IEDIndex3.cfm?tid=3&pid=3&aid=1
  2. Hall, C.A.S.; Powers, R.; Schoenberg, W. Peak Oil, EROI, investments and the economy in an uncertain future. In Biofuels, Solar and Wind as Renewable Energy Systems, 1st ed.; Pimentel, D., Ed.; Springer: Berlin, Germany, 2008; pp. 109-132.
  3. Downey, M. Oil 101, 1st ed.; Wooden Table Press: New York, NY, USA, 2009; p. 452.
  4. Hamilton, J.D. Historical oil shocks. Nat. Bur. Econ. Res. Work. Pap. Ser. 2011, 16790.
  5. Carruth, A.A.; Hooker, M.A.; Oswald, A.J. Unemployment equilibria and input prices: Theory and evidence from the United States. Rev. Econ. Stat. 1998, 80, 621-628.
  6. Hall, C.A.S.; Balogh, S.; Murphy, D.J.R. What is the minimum EROI that a sustainable society must have? Energies 2009, 2, 25-47.
  7. Canada’s Energy Future: Infrastructure changes and challenges to 2020—An Energy Market Assessment October 2009; Technical Report Number NE23-153/2009E-PDF; National Energy Board: Calgary, Alberta, Canada, 2010.
  8. Short-term Canadian Natural Gas Deliverability 2007-2009Short-term Canadian Natural Gas Deliverability 2007-2009 1/2007E; National Energy Board: Calgary, Alberta, Canada, 2007. Available online: http://www.neb-one.gc.ca/clf-nsi/rnrgynfmtn/nrgyrprt/ntrlgs/ntrlgsdlvrblty20072009/ ntrlgsdlvrblty20072009-eng.html
  9. Short-term Canadian Natural Gas Deliverability 2007-2009 Appendices; NE2-1/2007-1E-PDF; National Energy Board: Calgary, Alberta, Canada, 2007. Available online: http://www.nebone.gc.ca/clf-nsi/rnrgynfmtn/nrgyrprt/ntrlgs/ntrlgsdlvrblty20072009/ntrlgsdlvrblty20072009ppndceng.pdf
  10. Johnson, M. Energy Supply Team, National Energy Board, 444 Seventh Avenue SW, Calgary, Alberta, T2P 0X8, Canada; Personal communication, 2010.
  11. Natural Gas Potential in Canada – 2005 (CGPC – 2005). Executive Summary; Canadian Natural Gas Potential Committee: Calgary, Alberta, Canada, 2006. Available online: http://www.centreforenergy.com/documents/545.pdf (accessed on October 1, 2010)
  12. Murphy, D.J.; Hall, C.A.S. Order from chaos: A preliminary protocol for determining EROI of fuels. Sustainability 2011, 3, 1888-1907.
  13. 2009 Reference Case Scenario: Canadian Energy Demand and Supply to 2020—An Energy Market Assessment. Appendixes; National Energy Board: Calgary, Alberta, Canada, 2009. Available online: http://www.neb.gc.ca/clf-nsi/rnrgynfmtn/nrgyrprt/nrgyftr/2009/rfrnccsscnr2009ppndc- eng.zip (accessed on September 7, 2010)
  14. Hall, C.; Kaufman, E.; Walker, S.; Yen, D. Efficiency of energy delivery systems: II. Estimating energy costs of capital equipment. Environ. Manag. 1979, 3, 505-510.
  15. Bullard, C. The energy cost of goods and services. Energ. Pol. 1975, 3, 268-278.
  16. Cleveland, C. Net energy from the extraction of oil and gas in the United States. Energy 2005, 30, 769-782.
  17. Hendrickson, C.T.; Lave, L.B.; Matthews, H.S. Environmental Life Cycle Assessment of Goods and Services: An Input-Output Approach; RFF Press: Washington, DC, USA, 2006; p. 272.
  18. Carnegie Mellon University Green Design Institute Economic Input-Output Life Cycle Assessment (EIO-LCA), USA 1997 Industry Benchmark model. Available online: http://www.eiolca.net (accessed on October 1, 2010).
  19. Crude Petroleum and Natural Gas Extraction: 2002, 2002 Economic Census, Mining, Industry Series; EC02-21I-211111; U.S. Census Bureau: Washington, DC, USA, 2004.
  20. Natural Gas Liquid Extraction: 2002, 2002 Economic Census, Mining, Industry Series Natural Gas Liquid Extraction: 2002, 2002 Economic Census, Mining, Industry Series 21I-211112; U.S. Census Bureau: Washington, DC, USA, Appendices.
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  22. Canadian Petroleum Association. Statistical Handbook for Canada’s Upstream Petroleum Industry; Canadian Association of Petroleum Producers: Calgary, Canada, 2010.
  23. Statistics Canada Table 326-0021 Consumer Price Index (CPI), 2005 basket, annual (2002 = 100 unless otherwise noted). Available online: http://www.statcan.gc.ca/start-debut-eng.html (accessed on 20 September 2010).
  24. Annual Average of Exchange Rates 2002. Available online: http://www.cra-arc.gc.ca/tx/ndvdls/ fq/xchng_rt-eng.html (accessed on October 23, 2010) 2
  25. Lenzen, M. Life cycle energy and greenhouse gas emissions of nuclear energy: A review. Energy Convers. Manag. 2008, 49, 2178-2199.
  26. Pearce, J.M. Thermodynamic limitations to nuclear energy deployment as a greenhouse gas mitigation technology. Int. J. Nucl. Govern. Econ. Ecol. 2008, 2, 113-130.
  27. Mathur, J.; Bansal, N.K.; Wagner, H.-J. Dynamic energy analysis to assess maximum growth rates in developing power generation capacity: Case study of India. Energ. Policy 2004, 32, 281-287.
  28. Gas Resources, Technology and Production Profiles, Chapter 11. World Energy Outlook 2009; International Energy Agency: Paris, France, 2009.

 

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Drinking water and sewage treatment use a lot of energy

[ Water treatment (drinking and sewage) use tremendous amounts of energy. Some of the statistics from this document “Water & Wastewater Utility energy research roadmap” below are:

  • In 2008 municipal wastewater treatment systems (WWTP) in the United States used approximately 30.2 billion kilowatt hours (kWh) per year, or about 0.8% of total electricity used in the United States.
  • These WWTPs are becoming large energy consumers and they can require approximately 23% of the public energy use of a municipality.
  • About 10-40% of the total energy consumed by wastewater treatment plants is consumed for sludge handling.
  • Desalination consumes 3% of annual electricity consumption in the United States Future projections estimate this percentage to double to 6% due to higher water demand and more energy intensive treatment processes
  • A significant percentage of energy input to a water distribution system is lost in pipes due to friction, pressure and flow control valves, and consumer taps.
  • AWWA estimates that about 20% of all potable water produced in the United States never reaches a customer water meter mostly due to loss in the distribution system. When water is lost through leakage, energy and water treatment chemicals are also lost.
  • In California, agricultural groundwater and surface water pumping is responsible for approximately 60% of the total peak day electrical demand related to water supply, particularly the energy consumed within Pacific Gas and Electric’s (PG&E) controlled area. Over 500 megawatts (MW) of electrical demand for water agencies in California is used for providing water and sewer services to customers. The water related electrical consumption for the State of California is approximately 52,000 gigawatt hours (GWh). Electricity use for pumping is approximately 20,278 GWh, which is 8% of the state’s total electricity use. The remaining is consumed at the customer end side for heat, pressurize move and cool water.

This paper also looks at ways to save energy, and extraction of nutrients such as phosphorous — a good idea, since phosphate production may peak as soon as 40 years from now.

As global oil production declines and there isn’t enough energy to run civilization as we know it now, hard choices will need to be made.  First in line is agriculture, which consumes about 15 to 20% of energy in the U.S. to plant, harvest, store, distribute, cook, and so on.

Clean water and sewage treatment are just as important as food.  But drought threatens to increase energy requirements.   “The energy intensity of desalination is at least 5 to 7 times the energy intensity of conventional treatment processes”, so even though only 3% of the population is served by desalination, 18% of electricity used in the municipal water industry is for desalination plants.

But making water systems more energy efficient is trivial compared to trying to maintain and replace our aging water infrastructure, which is falling apart.

Alice Friedemann   www.energyskeptic.com  author of “When Trucks Stop Running: Energy and the Future of Transportation”, 2015, Springer and “Crunch! Whole Grain Artisan Chips and Crackers”. Podcasts: Practical Prepping, KunstlerCast 253, KunstlerCast278, Peak Prosperity , XX2 report ]

CEC. 2016. Water and wastewater utility energy research road map. California Energy Commission.  135 pages.

Excerpts:

ABSTRACT.  Water and wastewater utilities are increasingly looking for innovative and cost effective energy management opportunities to reduce operating costs, mitigate contributions to climate change, and increase the resiliency of their operations. The Water Research Foundation, the California Energy Commission and the New York State Energy Research and Development Authority jointly funded this project to assess the current state-of-knowledge on energy management, concepts and practices at water and wastewater utilities; understand the issues, trends and challenges to implement  energy projects; identify new opportunities to set a direction for future research; and develop a roadmap for energy research that includes a list of prioritized research, development, and demonstration projects on energy management for water and wastewater utilities.

EXECUTIVE SUMMARY.  The water industry faces challenges associated with escalating energy costs due to increased energy consumption and higher energy unit prices. Increased energy consumption is affected by energy-intensive treatment technologies needed to meet more stringent water quality regulations, growing water demand, pumping over longer distances, and climate change. More desalinated water to augment water supply shortages and the growth of groundwater augmentation is also anticipated.

The water industry faces challenges associated with escalating energy costs due to increased energy consumption and higher energy unit prices. Increased energy consumption is affected by energy-intensive treatment technologies needed to meet more stringent water quality regulations, growing water demand, pumping over longer distances, and climate change (GWRC, 2008). Moreover, the need for desalinated water to augment water supply shortages and the growth of groundwater augmentation is also anticipated (House, 2007). The same study by the Energy Commission estimates the demand for electricity in the water industry to double in the next decade. The water sector has shown only a limited response in implementing improvements that effectively address sustainability issues due to insufficient modernization, the presence of numerous regulatory and economic hurdles, and poor integration of energy issues within the water policy decision-making process (Liner and Stacklin, 2013; Rothausen and Conway, 2011).

Energy Management Opportunities in Wastewater Treatment and Water Reuse. Currently, there are over 15,000 municipal wastewater treatment plants (WWTPs), including 6,000 publicly owned treatment works (POTWs) providing wastewater collection and treatment services to around 78% of the United States’ population (Mo and Zhang, 2013; Spellman, 2013). According to the report published by EPRI and the WRF (Arzbaecher et al., 2013) in 2008 municipal wastewater treatment systems in the United States used approximately 30.2 billion kilowatt hours (kWh) per year, or about 0.8% of total electricity used in the United States. These WWTPs are becoming large energy consumers and they can require approximately 23% of the public energy use of a municipality (Means, 2004). Typical wastewater treatment operations have a total average electrical use of 500 to 4,600 kWh per MG treated, which varies depending on the unit operations and their efficiency (Kang et al., 2010; WEF, 2009; GWRC, 2008; NYSERDA, 2008a). Treatment-process power requirements as high as 6,000 kilowatt hours per million gallons (kWh/MG) are required when membrane bioreactors are used in place of activated sludge or extended aeration (Crawford & Sandino, 2010).

Approximately 2,000 million kWh of electricity are consumed annually by wastewater treatment plants in California (Rajagopalan, 2014). Energy use by these utilities is affected by influent loadings and effluent quality goals, as well as process type, size and age (Spellman, 2013). The majority of energy use occurs in the treatment process, for aeration (44%) and pumping (7%) (WEF, 2009). In major Australian WWTPs, the pumping energy for wastewater facilities ranged from 16 to 62% of the energy used for treatment (Kenway et al., 2008). In New York, the wastewater sector uses approximately 25% more electricity on a per unit basis (1,480 kWh/MG) than the national average (1,200 kWh/MG) due to the widespread use of energy intensive activated sludge, as well as compliance with stringent New York State effluent limits, which often require tertiary or other advanced treatment. Additionally, the predominance of combined (storm water and wastewater) sewer systems at the largest facilities, coupled with significant inflow and infiltration, result in extremely large variations in influent flow rates and loading, making efficient operations difficult (Yonkin et al., 2008).

The greatest potential for net positive energy recovery occurs at larger facilities, which are only a small percentage of the treatment works nationwide, but treat a large percentage of the nation’s wastewater. By achieving energy neutrality and eventually energy positive operations at larger facilities, the energy resources in the majority of domestic wastewater can be captured. This principle guided WERF to prepare a program to conduct the research needed to assist treatment facilities over 10 million gallons per day (MGD) to become energy neutral (Cooper et al., 2011). Energy self-sufficiency has been attained at a wastewater plant in Strass, Austria, where the average power usage is approximately 1,000 kWh/million gallon (MG) treated, which is also the approximate electricity generation from the sludge (Kang et al., 2010). The design employs two stages of aerobic treatment, with innovative controls, where biosolids generated in the two stages are thickened and anaerobically digested, with gas recovery and power generation. The centrate from the dewatering operation is treated in a sequencing batch reactor using the DEamMONification (DEMON) process to reduce the recirculation of nutrients to the head of the plant.

The importance of the scale of a facility in understanding the different strategies that may be implementable for the technology or service options available is pointed out in a recent report (AWE and ACEEE, 2013). It is important that energy management best practices are defined with consideration of specific plant size or treatment process. The largest per unit users of energy are, in fact, small water and wastewater treatment plants that treat less than 1 MGD, as well as those that employ an activated sludge with or without tertiary treatment process.

Wastewater treatment facilities have significant electricity demand during periods of peak utility energy prices. An effective energy load management strategy can help wastewater utilities to significantly reduce their electricity bills. A number of electrical load management opportunities are available to wastewater utilities (Table 2.1), notably by flattening the energy demand curve, particularly during peak pricing periods and by shifting major electrical demand to lower cost tariff blocks (e.g., overnight), for intra–day operations, or from season to season where long- or short-term wastewater or sludge storage is practical (NYSERDA, 2010). Wastewater treatment facilities have the potential to benefit from electric utility demand response (DR) opportunities, programs and tariffs. Although the use of integrated energy load management systems for wastewater utilities is still in its infancy, some wastewater utilities have begun implementing strategies that provide a foundation for participation in demand response programs. Such implementations are thus far limited to control pumping in lift stations of wastewater collection systems in utilities equipped with sufficient storage (Thompson et al., 2008). Wastewater treatment processes may offer other opportunities for shifting wastewater treatment loads from peak electricity demand hours to off-peak hours, as part of Demand Management Programs (DMPs), by modulating aeration, backwash pumps, biosolids thickening, dewatering and anaerobic digestion for maximum operation during offpeak periods. Recently, wastewater utilities, such as the Camden County Municipal Utilities Authority, have developed a computerized process system that shaved the peaks by avoiding simultaneous use of energy-intensive process units, to the maximal extent possible, thereby minimizing the peak charge from the energy provider (Horne and Kricun, 2008). In addition, the East Bay Municipal Utilities District has implemented a load management strategy which stores anaerobic digester gas until it can be used for power generation during peak-demand periods. Another opportunity for shifting electrical loads from on-peak to off-peak hours is over-oxygenating stored wastewater prior to a demand response event, then turning off aerators during peak periods without compromising effluent quality (Thompson et al., 2008). For a wastewater facility to successfully implement demand response programs, advanced technologies that enhance efficiency and control equipment are needed, such as a comprehensive and real-time demand control from centralized computer control systems that can provide an automatic transfer switch to running onsite power generators during peak demand periods, in accordance with air quality requirements (Thompson et al., 2008).

An interesting opportunity for reducing energy use in municipal wastewater treatment is to improve storm water management (Lekov, 2010). The adoption of stormwater treatment only at CSO communities can reduce energy consumption for wastewater treatment systems due to reductions in volume at the treatment plant and reduction in volumes requiring pumping in the combined sewer collection system.

Wastewater utilities are actively working to reduce the energy use of their facilities by increasing efficiency. Energy efficiency is part of the process to reduce energy demand along the path to a net energy neutral wastewater treatment plant. Briefly, wastewater treatment plants can target energy efficiency by replacing or improving their core equipment, through use of variable frequency devices (VFDs), appropriately sized impellers and implementation of energy-saving automation schemes. Efficiency can also be improved at the process level, by implementing low energy treatment alternatives to an activated sludge process or improving process control.

Energy Efficient Equipment. There are numerous types of energy efficient equipment that a wastewater utility can utilize to reduce energy consumption. Common facility-wide plant improvements include upgrade of electric motors and the installation of VFDs in pumps. These modifications can result in substantial energy efficiency because at least 60% of the electrical power fed to a typical wastewater treatment plant is consumed by electric motors (Spellman, 2013). VFDs enable pumps to accommodate fluctuating demand and allow more precise control of processes. VFDs can reduce a pump’s energy use by up to 50% compared to a motor running at constant speed for the same period. Wastewater treatment facilities can also upgrade their heating, cooling, and ventilation systems (HVAC) to improve energy efficiency and reduce energy costs. The latest developments in HVAC equipment can substantially reduce cooling energy use by approximately 30 to 40% and achieve energy efficiency ratios as high as 11.5. The latest air-source heat pumps can reduce heating energy use by about 20 to 35%. Water-source heat pumps also have superior ratings, especially when outside air temperatures drop below 20 degrees Fahrenheit (°F) (15.2 energy efficiency ratio) and can use heat from treated effluent to supply space heating. The Sheboygan Wastewater Treatment Plant reduced its energy consumption by 20% from 2003 solely by implementing energy demand management strategies that targeted efficiency by equipment replacement (e.g., motors, VFDs, blowers, etc.) and scheduling of regular maintenance (Liner and Stacklin, 2013).

Wastewater treatment plants have also recently used advanced sensors and control devices to optimize energy so that what is supplied meets but does not exceed the actual demand. For example, the adoption of lower dissolved oxygen set-points in the aeration basin can still maintain microbial growth and generate energy savings of 15-20% (Kang et al., 2010). The installation of energy submeters is another important plant improvement that, however, can require high capital investments for a utility. Recent advances in lamps, luminaries, controls, and lighting design provide numerous advantages over traditional lighting systems. Since lighting accounts for 35 to 45% of the energy use of an office building, the installation of high-efficiency alternatives for nearly every plant can dramatically reduce the operational energy bill for the utility. Incentives and rebates are commonly available from electric utilities and other agencies, such as NYSERDA, to support the installation of energy-efficient fixtures and equipment that reduce energy use financial impacts

Aeration is the largest energy user in a typical wastewater treatment plant, thus the aeration process should be evaluated when implementing energy reduction programs. Installing automatic dissolved oxygen control enables continuous oxygen level monitoring in the wastewater and so that aerators can be turned off when the oxygen demand is met. Based on the aeration capacity of the wastewater treatment system and the average wastewater oxygen requirement, the automated dissolved oxygen control can be the most cost effective method to optimize aeration energy and achieve energy savings up to 25% to 40% if compared to manually controlled systems. In addition to automated control systems, the installation of smaller modular and high efficiency blowers to replace centralized blowers, the proximity of the blowers to the aeration basin to reduce energy losses from friction, and the installation of high efficiency pulsed air mixers are important efficiency measure to be considered.

About 10-40% of the total energy consumed by wastewater treatment plants is consumed for sludge handling. Most of the energy required is due to the shear force applied for dewatering, solids drying and treatment of high-strength centrate. As an example, in California centrifuge and belt filter presses consume 30,000 kWh/year/MGD and 2-6,000 kWh/year/MGD, respectively (Rajagopalan, 2014). Many studies have been conducted on understanding sludge dewatering processes and improving their efficiency. Recent studies by the Energy Commission have focused on the improvement of sludge dewatering to achieve lower energy consumption by using nanoparticulate additives. By implementing this solution at wastewater treatment plants in California, the state would be able to save an additional 10.5 million kWh per year, which includes the cost of energy, polymer and nanoadditives for sludge dewatering, and sludge disposal

Another innovation directed toward more energy efficient systems is the use of distributed systems in place of the centralized treatment systems historically favored due to their economies of scale. Centralized plants are generally located down gradient in urban areas, permitting gravity wastewater flow to the treatment plant, while the demand for reclaimed wastewater generally lies up gradient. This means higher energy demands for pumping the reclaimed wastewater back to the areas in need. These energy costs can be reduced through use of smaller distributed treatment plants located directly in water limited areas

Processes and technologies already in use at wastewater treatment plants include biogas-powered combined heat and power (CHP), thermal conversion from biosolids, renewable energy sources (e.g., systems solar arrays and wind turbines), energy recovery at the head of the wastewater treatment plant and within the treatment process.

Energy recovery from anaerobic digestion with biogas utilization and biosolids incineration with electricity generation is widespread, but there is potential for further deployment. Of the approximately 837 biogas generating facilities in the United States, only 35% generate electricity from biogas and only 9% sell electricity back to the grid (Liner and Stacklin, 2013). The low application rate is partly due to the

dominance of small wastewater systems in the United States (less than 5 MGD). It is estimated that anaerobic digestion could produce about 350 kWh of electricity for each million gallons of wastewater treated at the plant and save 628 to 4,940 million kWh annually in the United States (Stillwell et al., 2010). The electricity produced by CHPs is reliable and consistent, but the installation requires relatively high one-time capital costs. Research shows that recovery of biogas becomes cost-effective for wastewater treatment plants with treatment capacities of at least 5 MGD (Mo and Zhang, 2013; Stillwell et al., 2010). Various wastewater treatment plants, such as by the East Bay Municipal Utility District (Oakland, California) and the Strass WWTP (Austria) became a net-positive, energy-generating wastewater plant by powering low-emission gas turbines with biogas from co-digestion processes.

Biosolids incineration with electricity generation is an effective energy recovery option that uses multiple hearth and fluidized bed furnaces.  Both incineration technologies require cleaning of exhaust gases to prevent emissions of odor, particulates, nitrogen oxides, acid gases, hydrocarbons, and heavy metals.

As for biogas-generating electricity, incineration can be used to power a steam cycle power plant, thus producing electricity in medium to large wastewater treatment plants where a high amount of solids is produced.

Disadvantages of incineration are high capital investments, high operating costs, difficult operations, and the need for air emissions control (Stillwell et al., 2010). Despite these disadvantages, biosolids incineration with electricity generation is an innovative approach to managing both water and energy. For example, the Hartford Water Pollution Control Facility in Hartford (Connecticut) is incorporating an energy recovery facility into their furnace upgrade project and they anticipate that biosolids incineration will generate 40% of the plant’s annual electricity consumption (Stillwell et al., 2010).

Wastewater utilities can now strategically replace incineration with advanced energy recovery technologies (MWH Global, 2014). Like incineration, gasification and pyrolysis offer the potential to minimize the waste mass for ultimate disposal from processing sewage sludge for its sludge treatment centers and also offer the prospect of greater energy recovery and/or lower operating cost than that offered by incineration (MWH Global, 2014). The range of gasification technologies available is large and at present it is believed that there are further synergies, such as recovering heat for digester and/or thermal hydrolysis process heating, that can be derived for a digestion or advanced digestion/ gasification advanced energy recovery. Pyrolysis, offers further advantages over the gasification options due to the production of a better syngas product than gasification, favoring more effective gas engine/CHP power generation.

Nutrient recovery from wastewater can offset the environmental loads associated with producing the equivalent amount of fertilizers from fossil fuels (Mo and Zhang, 2013). Various nutrient recovery methods have been applied in wastewater treatment processes and include biosolids land application, urine separation, controlled struvite crystallization and nutrient recovery through aqua-species. Biosolids land application involves spreading biosolids on the soil surface or incorporating or injecting biosolids into the soil. Urine separation involves separation of urine from other wastewater sources for recovery of nutrients. The process is promising in terms of maximizing nutrient recovery from wastewater, because around 70-80% of nitrogen and 50% of phosphorus in domestic wastewater is contained in urine (Maurer et al., 2003).

Although not widely applied, aqua-species, such as macroalgae, microalgae, duckweed, crops and wetland plants after utilizing nutrients in wastewater, can be harvested and used as fertilizers or animal feeds

While these individual resource recovery methods have been studied, there is a paucity of peer-reviewed articles focusing on the current status and sustainability of these individual methods as well as their integration at different scales

Recently, a few research programs have started investigating the potential for nutrient recovery, including carbon, nitrogen and phosphorus from wastewater treatment process. A recent report from WERF with support from the Commonwealth Scientific and Industrial Research Organization (CSIRO), Resource Recovery from Wastewater: A Research Agenda, summarized and defined the future research needs for the resource recovery opportunities in the wastewater sector (Burn et al., 2014).

WERF is developing a tool for the implementation and acceptance of resource recovery technologies at WWTPs, with a major focus on extractive nutrient (phosphorus) recovery technologies that employ greater energy efficiency and offer monetary savings (Latimer, 2014). WERF has prioritized high profile research on P concentration and recovery opportunities during wastewater treatment processes. Polyphosphate-accumulating organisms (PAO) can be responsible for P concentration in cells and direct concentration and precipitation of struvite that can be recovered for niche agricultural markets (Burn et al., 2014). This report implies that nitrogen recovery seems to be a lower priority than carbon (through biogas) or phosphorus recovery, unless combined with other recovery opportunities. N recovery is possible through the use of adsorption/ion-exchange, precipitation and stripping processes.

A $26 million ion-exchange pilot facility in New York that concentrated ammonia from recycle streams (centrate) of anaerobically digested sludge showed that the above mentioned methods are viable, however not yet as cost effective as the Haber-Bosch process (Burn et al., 2014).

Treated wastewater can be reused for various beneficial purposes to provide ecological benefits, reduce the demand of potable water and augment water supplies (Mo and Zhang, 2013). Beneficial uses include agricultural and landscape irrigation, toilet flushing, groundwater replenishing and industrial processes (EPA, 2004). Currently, around 1.7 billion gallons per day of wastewater is reused in the US, and this reuse rate is growing by 15% every year (Mo and Zhang, 2013) and Florida and California are pioneering states in the country focusing on water reuse. The level of wastewater treatment required varies depending on the regulatory standards, the technologies used and the water quality characteristics. Some of the treatment process or schemes utilized are able to save energy for the same amount of water delivered.

Although there is integrated resource recovery in practice currently, particularly at the community level, the related studies are rare. In a WWTP in Florida onsite energy generation, nutrient recycling and water reuse are combined: CHP is used to generate electricity from the digested gases, biosolids are sold for land application and part of the treated water is used for agricultural and landscape irrigation. In general, to date, very limited studies have reviewed the integrated energy-nutrient-water recovery in WWTPs, particularly on a national-scale (McCarty et al., 2011; Mo and Zhang, 2013; Verstraete et al., 2009) and there are no studies optimizing the resource recovery via multiple approaches

Energy Management Opportunities in Drinking Water and Desalination. Desalination consumes 3% of annual electricity consumption in the United States (Boulos and Bros, 2010; EPA, 2012b; Sanders and Webber, 2012; Arzbaecher et al., 2013). Future projections estimate this percentage to double to 6% due to higher water demand and more energy intensive treatment processes (Chaudhry and Shrier, 2010). Estimates indicate that approximately 90% of the electricity purchased by water utilities, or approximately $10 billion per year, is required for pumping water through the various stages of extraction, treatment, and final distribution to consumers (Bunn, 2011; Skeens et al., 2009). Despite recent energy efficiency progress in pumping systems, there has not been any notable impact on existing energy intensity values. Furthermore, the energy use in drinking water utilities, with the exclusion of energy use for water heating by residential and commercial users, contributes significantly to an increasing carbon footprint with an estimated 45 million tons of greenhouse gases (GHG) emitted annually in the UnitedStates.

In California, agricultural groundwater and surface water pumping is responsible for approximately 60% of the total peak day electrical demand related to water supply, particularly the energy consumed within Pacific Gas and Electric’s (PG&E) controlled area. Over 500 megawatts (MW) of electrical demand for water agencies in California is used for providing water and sewer services to customers (House, 2007). The water related electrical consumption for the State of California is approximately 52,000 gigawatt hours (GWh) (House, 2007). Electricity use for pumping is approximately 20,278 GWh, which is the 8% of the state’s total electricity use. The remaining is consumed at the customer end side for heat, pressurize move and cool water.

To address the challenges associated with poorer quality sources and/or reduced supply, water utilities have been exploiting new water supply options such as seawater and saline groundwater, the use of which is growing about 10% each year. The use of these new water sources require two to ten times more energy per unit of water treated than traditional water treatment technologies.

While previous studies have focused on energy requirements for water utilities, there is a lack of studies that estimate peak electric demand and peak use in the water sector (House, 2007). This lack of understanding of peak electrical demand and use is even more limited by the lack of water demand profiles that can be compared to electric use profiles in the water sector. Development of water demand profiles is very difficult and not monitored as well as electric use, due to the fact that water is billed by volume and not by time-of-use (House, 2007). Pricing water in a TOU structure is still a complicated task for water utilities, however it has the potential to offer large energy savings.

In many cases, successful water efficiency programs reduce the total revenues for water agencies under typical rate structures

Research is needed to investigate the potential for decoupling investments from revenues in water markets and other financial methods that would make conservation and efficiency programs more attractive and encourage alternative energy supplies. Better valuing of the different qualities and sources of water would also facilitate better choices of water resource applications that take the real cost/value of the supply and quality into consideration.

Energy Efficiency Estimates indicate that between 10 and 30% cost savings are readily achievable by almost all utilities implementing energy efficient programs or strategies (Leiby and Burke, 2011). In addition to cost savings, improving efficiency will result in a number of benefits, including the potential to reinvest in new infrastructure or programs, reduce the pressure on the electrical grid, achieve

Energy efficient processes and new technologies to be applied in the water treatment and desalination sector are still at the research stage or are under-development. For example, NeoTech Aqua Solutions, Inc. has developed a new ultraviolet (UV) disinfection technology (D438) that uses 1/10 of the energy compared to lamps required in similar flow conventional UV systems. The technology demands less electricity and results in a smaller electrical bill, less maintenance, and a smaller overall carbon footprint.

Estimates of energy efficiency in water supply and drinking water systems, associated economics and related guidelines are lacking.

Energy Efficient Operations and Processes

Energy efficiency can be targeted in water supply and distribution system operations as well as water treatment. Efficient pump scheduling and network optimization are significant contributors to efficiency practices

A significant percentage of energy input to a water distribution system is lost in pipes due to friction, pressure and flow control valves, and consumer taps (Innovyze, 2013).

The energy intensity (kWh per MG of water treated) of desalination is at least 5 to 7 times the energy intensity of conventional treatment processes, so even though the population served by desalination is only about 3%, we estimate that approximately 18% of the electricity used in the municipal water industry is for desalination plants. Due to the lower energy consumption, RO processes are preferred to thermal treatments for domestic water desalinization in the United States.

In an RO process, costs associated with electricity are 30% of the total cost of desalinated water. Reducing energy consumption is critical for lowering the cost of desalination and addressing environmental concerns about GHG emissions from the continued use of conventional fossil fuels as the primary energy source for seawater desalination plants.

The feed water to the RO is pressurized using a high pressure feed pump to supply the necessary pressure to force water through the membrane to exceed the osmotic pressure and overcome differential pressure losses through the system

Typically, an energy recovery device (ERD) in combination with a booster pump is used to recover the pressure from the concentrate and reduce the required size of the high pressure pump (Stover, 2007; Jacangelo et al., 2013). A theoretical minimum energy is required to exceed the osmotic pressure and produce desalinated water. As the salinity of the seawater or feed water recovery increases, the minimum energy required for desalination also increases. For example, the theoretical minimum energy for seawater desalination with 35,000 milligrams per liter (mg/L) of salt and a feed water recovery of 50% is 1.06 kilowatt hours per cubic meter (kWh/m3)(Elimelech and Philip, 2011). The actual energy consumption is larger as real plants do not operate as a reversible thermodynamic process

Typically, the total energy requirement for seawater desalination using RO (including pre- and post-treatment) is on the order of 3 – 6 kWh/m3 (Semiat, 2008; Subramani et al., 2011). More than 80% of the total power usage by desalination plants is attributed to the high pressure feed pumps

The energy consumption associated with filtration systems increases due to fouling by nanoparticles as reported in a study from the Energy Commission (Rosso and Rajagopalan, 2013). For example, flux analysis of MF 200 nanometer (nm) pore size membranes showed that particles between 100 and 2.5 nm contributed the most to the membrane fouling, more than fouling due to cake formation. Further understanding of the mechanisms of membrane fouling and of pretreatment options with coagulants will offer energy savings opportunities for water and water reclamation utilities

AWWA estimates that about 20% of all potable water produced in the United States never reaches a customer water meter mostly due to loss in the distribution system. When water is lost through leakage, energy and water treatment chemicals are also lost.

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