It is rare to see a professor come out and cheerlead a new technology, even if he is the father of the process. In this case it seems a well earned right. THAI or toe and heel air injection is proving to be far better than anticipated and making the projected improvements much more probable. This article was published a couple of months ago and this last week we have also seen the THAI story been told on the national news. I have been keeping a watchful brief on the pilot test from before it got funded. This is actually a remarkable discovery, and its real success infield is wonderful. Personal experience kept me cautious until I saw the early production results. We all can now throw that caution to the wind.
I believe that this will also access huge reserves of conventional oil that is now classified as dead oil. Of course a lot of those fields will have to be dried out. However, any sandstone based reservoir that is reasonably thick should be exploitable. You will notice particularly that they are quoting an amazing 70% to 80% recovery and in well catalytic upgrading to as high as 26 api. Of course, they are now getting a bit over the top. However, I certainly can anticipate resources for which these levels may be possible.
In fact, I suspect that a lot of oil companies will be rather sorry that they ever used water floods at all. For the layman, natural flow will deliver up to perhaps 40% of in place oil. The truth is that this is more like 30 to 35%. Water floods will sweep out maybe another 15%. This means that generally, half of the original oil remains behind. And it is rather unlikely that a wet formation can be made to work with this method, although I reserve the right to be surprised.
The power of this method comes from the fact that the air is under pressure permitting the development of a 600 degree burn zone. This is hot enough to encourage reforming of the oil, to say nothing about its liquefaction. On top of that the combustion product is CO2, CO and steam (H2O) as well as entrained nitrogen. All these gases except H2O dissolve into the oil itself helping to improve its viscosity. These gases also dissolve into the water helping to break the oil free of the sand itself.
The only escape for all this heat is with the production fluid itself or through a very slow leaking into the surrounding non porous sediments. This is also true of the production gases which will tend to penetrate the formation ahead of the burn front speeding the process up.
I expect that it will be possible to set up a 100 well burn front within the formation that will obviate any need for pillars or untreated zones between burns. It also seems that as the burn front gets a fair distance down the formation, it will be good practice to place additional injection wells at the burn front and seal the older wells.
In fact there is little reason not attempt to treat one hundred percent of the formation with a closely managed burn front that is moved slowly along with additional production and injection wells placed as needed.
I am particularly encouraged with the experiments starting with using 3d seismic mapping to follow the location of the burn front. If this works, then it will be possible to almost micro manage the system.
The real payoff with this system is that it uses drilling industry resources which are sufficient and fully in place in Alberta to swiftly add a million new barrels of production every year. Each well pair will pump out 1000 barrels per day. With air injection and a full sand handling system, they are not cheap, but they are not unusual and will certainly meet the industry standard of a three year payback with absolutely no discovery risk.
Since this all works best on oil that is likely below the mining zone, we have likely added all of Canada’s oil sands to the world’s oil inventory. I believe that this will easily exceed one trillion barrels, though up to now measurement has never been much of a priority. I also remember seeing a map once in which the tar sands were shown to extend far north along the McKenzie Valley. I think every one just gave up once they found a trillion. I suspect accurate measurement just became important again.
Toe-to-Heel Air Injection (THAI™) System
Published Thu, 2007-11-29 16:08 Energy
A new method developed in Britain over the past 17 years for extracting oil is now at the forefront of plans to exploit a massive heavy oilfield in Canada.
Duvernay Petroleum is to use the revolutionary Toe-to-Heel Air Injection (THAI™) system developed at the University of Bath at its site at Peace River in Alberta, Canada.
Unlike conventional light oil, heavy oil is very viscous, like syrup, or even solid in its natural state underground, making it very difficult to extract. But heavy oil reserves that could keep the planet’s oil-dependent economy going for a hundred years lie beneath the surface in many countries, especially in Canada.
Although heavy oil extraction has steadily increased over the last ten years, the processes used are very energy intensive, especially of natural gas and water. But the THAI™ system is more efficient, and this, and the increasing cost of conventional light oil, could lead to the widespread exploitation of heavy oil.
“The world needs to switch to cleaner ways of using energy such as fuel cells,” said Professor Malcolm Greaves, who developed the THAI™ process.
“But we are decades away from creating a full-blown hydrogen economy, and until then we need oil and gas to run our economies.
“Conventional light oil such as that in the North Sea or Saudi Arabia is running out and getting more expensive to extract.
“That’s why the pressure is on to find an efficient way of extracting heavy oil.”
THAI™ uses a system where air is injected into the oil deposit down a vertical well and is ignited. The heat generated in the reservoir reduces the viscosity of the heavy oil, allowing it to drain into a second, horizontal well from where it rises to the surface.
THAI™ is very efficient, recovering about 70 to 80 per cent of the oil, compared to only 10 to 40 per cent using other technologies.
Duvernay Petroleum’s heavy oil field in Peace River contains 100 million barrels and this will be a first test of THAI™ on heavy oil, for which THAI™ was originally developed. Duvernay Petroleum has signed a contract with the Canadian firm Petrobank, which owns THAI™, to use the process.
The THAI™ process was first used by Petrobank at its Christina Lake site in the Athabasca Oil Sands, Canada, in June 2006 in a pilot operation which is currently producing 3,000 barrels of oil a day. This was on deposits of bitumen - similar to the surface coating of roads - rather than heavy oil.
Petrobank is applying for permission to expand this to 10,000 barrels a day though there is a potential for this to rise to 100,000.
The 50,000 acre site owned by Petrobank contains an estimated 2.6 billion barrels of bitumen. The Athabasca Oil Sands region is the single largest petroleum deposit on earth, bigger than that of Saudi Arabia.
Professor Greaves, of the University’s Department of Chemical Engineering, said: “When the Canadian engineers at the Christina Lake site turned on the new system, in three separate sections, it worked amazingly well and oil is being produced at twice the amount that they thought could be extracted.
“It’s been quite a struggle to get the invention from an idea to a prototype and into use, over the last 17 years. For most of the time people weren’t very interested because heavy oil was so much more difficult and expensive to produce than conventional light oil.
“But with light oil now hitting around 100 dollars a barrel, it’s economic to think of using heavy oil, especially since THAI™ can produce oil for less than 10 dollars a barrel.
“We’ve seen this project go from something that many people said would not work into something we can have confidence in, all in the space of the last 18 months.”
Professor Greaves, who was previously Assistant Professor at the University of Saskatchewan in Canada, and who also worked with Shell and ICI in the UK, is looking at making THAI™ even more efficient using a catalyst add-on process called CAPRI™.
This process was also developed by Professor Greaves’ team at Bath and is intended to turn heavy oil into light while still in the reservoir underground. The CAPRI™ research has recently been awarded funding of £800,000 from Engineering and Physical Sciences Research Council, including £60,000 from Petrobank. The project collaborators are Dr Sean Rigby, from the Department of Chemical Engineering at Bath, and Dr Joe Wood of the University of Birmingham.
Source: University of Bath
