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January 26, 2008

Bakken and Torquay Formations - A Saudi Arabia of oil under Saskatchewan, North Dakota, South Dakota, Montana and Manitoba

MORE NEWS
There is a separate North Dakota study of the Bakken and a link to where the state publishes online reports of completed wells and wells with reported production. A bunch of wells were reported on April 28, 2008.

BREAKING NEWS
Well my guess was far to optimistic. The USGS 2008 figure was 3.65 billion barrels of oil for the US part of the Bakken formation.

UPDATE: Bakken in the context of the world's oil megaprojects. About 7 million barrels per day being added in 2008 and 2009 from about 50 projects per year.

The Bakken oil formation is possibly the largest conventional oil discovery in Canada since 1957. If this oil formation plays out toward the higher end of size and recoverability then it will change the geopolitics of oil and the economies of the United States and Canada. If a lot of the oil proves difficult to recover now, new technologies could still drastically improve the percent recoverable. The motivation to pull out another 100 billion barrels would be $9 trillion at todays prices. UPDATE:Here is my article on multi-stage fracturing (Stackfrac) horizontal drilling.

This thursday, April 10, 2008 the new US Geological survey will be released on the potential of the Bakken

Estimates are anywhere from a conservative 25 billion barrels of oil in place, to a high estimate by the United States Geological Survey of 400 billion barrels of oil in the Bakken formation. Not only is the oil plentiful, but it's high quality too, 41 degree light sweet crude. The Bakken formation is a formation of black shale, siltstone, and sandstone. The formation lies beneath the Mississippian formation, Saskatchewan's current source of light sweet crude. The Bakken formation is situated beneath southeastern Saskatchewan, southwestern Manitoba, and North Dakota.


In 2007, EOG Resources out of Houston, Texas reported that a single well it had drilled into an oil-rich layer of shale below Parshall, North Dakota is anticipated to produce 700,000 barrels of oil.


The resources of the Bakken Formation are defined by the United States Geological Survey (USGS) as unconventional “continuous-type” oil resources. This means the hydrocarbons within the Bakken have not accumulated into discrete reservoirs of limited areal extent. With new horizontal drilling and completion technology taken into account, the technically recoverable resource base for the entire Bakken Formation is potentially much larger.



Isopach map of the Bakken formation in Saskatchewan, Canada (Map of the areal extent and thickness variation of a stratigraphic unit; used in geological exploration for oil and for underground structural analysis)



The Williston Basin covers approximately 300,000 square miles over parts of North Dakota, South Dakota, and Montana and parts of the adjacent Canadian provinces of Saskatchewan and Manitoba. The Bakken formation can be encountered throughout the Williston Basin.

Application of new drilling and completion technology has begun to unlock new potential in this legacy basin. There is speculation that the total resource in the play could be in the billions of barrels.



Hydrocarbon Potential of the Bakken and Torquay Formations,
Southeastern Saskatchewan by L.K. Kreis and A. Costa


Much of the oil reservoired within the Bakken shale likely resides in a network of enhanced porosity and permeability related to microfractures.

• Upper and Lower Bakken shales showing anomalously high resistivity values in southeastern Saskatchewan suggest that they are saturated with oil that has either been generated in place or has migrated into these locations.

• Basement structures, such as those associated with the Brockton-Froid lineament, and compactional features in regions of Middle Devonian salt dissolution may control fractures that serve as primary migration pathways for Bakken-sourced oils into possible plays in the Bakken and Torquay formations.

• The relatively low permeability of Bakken and Torquay reservoirs are likely best exploited through horizontal wells.

• A large untested and poorly evaluated rock volume remains in the Bakken and Torquay formations of southeastern Saskatchewan, within which there may be significant potential for finding new oil.


Porosities in the Bakken average about 5%, and permeabilities are very low, averaging 0.04 millidarcies—much lower than typical oil reservoirs. However, the presence of horizontal fractures makes the Bakken an excellent candidate for horizontal drilling techniques in which a well drills along the extent of the rock layer, rather than punching a hole vertically through it. In this way, many thousands of feet of oil reservoir rock can be penetrated in a unit that reaches a maximum thickness of only about 140 feet. Production is also enhanced by artificially fracturing the rock.



Oils with an API gravity of 40 to 45 have the highest market price and those with values outside this range sell for less. Above an API gravity of 45, the molecular chains become shorter and are less valuable to a refinery. Crude oil classified as light, medium or heavy, on the following basis:
Light crude oil has an API gravity of above 31.1 °.
Medium oil has an API gravity in the range 22.3 ° and 31.1 °.
Heavy oil has an API gravity less than 22.3.


FURTHER READING
EOG Resources has about $5 million direct drilling costs and is recovering that in about 6 months

Petrobank in Saskatchewan has about $1.7 million drilling and completion costs with costs recovered well within one year.

In 1992, Energy and Mines estimated there was roughly 100 billion barrels of oil in the Bakken formation throughout the entire Williston Basin.

Dancsok, who co-authored the 1991 study, said the prevailing view in the geoscience community at the time was "the potential of the Bakken was immense, but the price of oil in 1991 was not such that people wanted to risk (exploration and development dollars)."

Dancsok estimated roughly 25 per cent of the Williston Basin, which covers some 200,000 square miles (518,000 square kilometres) is located in Saskatchewan. Based on that simple arithmetic, the estimate of Bakken oil in the province could range anywhere from 25 billion barrels to 100 billion barrels of oil in place.

Of course, geology isn't that simple.

"Whether the Bakken is evenly distributed throughout the basin is one question," Dancsok said. "It is deeper in North Dakota. But is the distribution of Bakken oil equal in Saskatchewan to North Dakota or Montana? That's a big question mark."


Research documents for purchase from the Saskatchewan government

North Dakotas Bakken Reserve estimates

New estimates of the amount of hydrocarbons generated by the Bakken were
presented by Meissner and Banks (2000) and by Flannery and Kraus (2006). The first of
these papers tested a newly developed computer model with existing Bakken data. Data
used was not as extensive as some of the other studies mentioned in this discussion
therefore estimates of generated oil presented were 32 BBbls. The second paper by
Flannery and Kraus used a more sophisticated computer program with extensive data
input supplied by the ND Geological Survey and Oil and Gas Division. Early numbers
generated from this information placed the value at 200 BBbls (pers. comm. Jack
Flannery, 2005). Estimates had been revised to 300 BBbls when the paper was presented
in 2006. Even if the lower value of 32 BBbls is correct, the amount that may be
potentially recovered from the Bakken is significant.

How much of the oil that has been generated is technically recoverable is still to
be determined. Price places the value as high as 50% recoverable reserves. A primary
recovery factor of 18% was recently presented by Headington Oil Company for their
Richland County, Montana wells. Values presented in ND Industrial Commission Oil
and Gas Hearings have ranged from 3 to 10%. The Bakken play in the North Dakota side
of the basin is still in the learning curve. North Dakota wells are still undergoing
adjustments and modifications to the drilling and completion practices used for this
formation. It is apparent that technology and the price of oil will dictate what is
potentially recoverable from this formation.


New cheap computer modeling could allow access to about 218 billion barrels of oil that is still in the ground in the USA in old wells and less economical fields.

Microwave oil recovery could make it cheaper to extract a lot more oil from oil shale (up to 800 billion barrels in the USA extractable) and from the oil sands. (Up to 2 trillion barrels in Canada's oilsands.

Al Fin also has a feature on the Toe to Heel Air Injection (THAI) technology for extracting oil from tar sands deposits.

A posting and msg board related to the EOG Resources well

EOG resources website

In the United States EOG’s total crude oil and condensate production increased 23 percent compared to the same quarter a year ago, driven by continued drilling success in North Dakota and the Mid Continent.

EOG announced 2008 total company production growth targets, ranging from 13 to 17 percent, depending on drilling economics and North American natural gas prices. Production growth in 2008 will be driven by United States operations, particularly the Fort Worth Basin Barnett Shale natural gas and the North Dakota Bakken crude oil plays, both very high rate of return programs



2007 EOG Resources SEC filings

In the United States, EOG's total crude oil and condensate production increased 23 percent compared to the same quarter a year ago, driven by continued drilling success in North Dakota and the Mid Continent.

In Mountrail County, North Dakota, EOG has reported successful drilling from the Bakken Formation. The Wenco #1-30H, in which EOG has a 52 percent working interest, was completed to sales at the end of September at an initial production rate of 1,930 barrels of oil per day (Bopd), gross. Also in Mountrail County, the Austin #1-02H was completed to sales in October at an initial production rate of 2,000 Bopd. EOG has a 100 percent working interest in the well, which is located nine miles north of existing production. This is the northernmost location that EOG has drilled to date. To further confirm the northern extension of the field, following completion of the Austin #1-02H, EOG drilled an offset well, the Austin #2-03H that will be completed in November. Based on shows during drilling, EOG expects the well to produce at a rate similar to that of the Austin #1-02H. EOG has an 81 percent working interest in the Austin #2-03H. In the North Dakota Bakken Play, where it has accumulated over 175,000 net acres, EOG plans to increase drilling activity from six to eight rigs in early 2008.

"The results from the two Austin wells have given us the confidence to increase estimated reserves in the Bakken Play from the previously announced 60 million barrels of oil to approximately 80 million barrels, net to EOG. By extending the perimeter of the field, we have also increased our inventory of firm drilling locations. Therefore, we expect this area to have a significant impact on EOG's oil production in 2008 and beyond. The Bakken is currently the highest rate of return play in our drilling program," said Mark G. Papa, Chairman and Chief Executive Officer


North Dakota Bakken

Zacher 1-24H - EOG has a 75 percent working interest in the Zacher 1-24H that was completed in June with a peak production rate of 1,774 barrels of oil per day (Bopd), gross.
Hoff 1-10H - EOG has a 75 percent working interest in the Hoff 1-10H, which began flowing to sales in June at a peak rate of 2,034 Bopd, gross.
N&D 1 - 05H - EOG holds a 67 percent working interest in the N&D 1-05H, which was completed in July at an initial peak production rate of 1,610 Bopd, gross.


Rocky Mountain Oil Journal: EOG Confirmed to Have Significant Producer North of Parshall Field

EOG Resources (EOG) has confirmed that its wildcat 10 miles north of Parshall Field is a large volume, horizontal Bakken producer. According to EOG’s 2007 Third Quarter results, the Austin #1-02H, a single-lateral test in the sw-se 2-154n-90w, Mountrail County, has been producing at an initial rate of 2,000 bopd. EOG has a 100 percent working interest in the #1-02H. Parshall Field is the largest Bakken oil pool discovered in North Dakota with a monthly production exceeding 200,000 bo. The company believes that this well is connected to Parshall Field, and if geological data supports this, Parshall Field could be a Class A oil field (100 mmbo +). Not only did EOG confirm the huge rates on the Austin #1-02H, the company also said that its first stepout to this well, the Austin #2-03H sw-se 3-154n-90w, will also produce at similar rates based on shows encountered during the drilling of this well. The #2-03H scales about one mile west of the of the 1-02H.




drillers added fracture technology to horizontal drilling. In fracture technology, mud is forced into the drilled hole under immense pressures to "frack" or break up the shale further. The deeper cracks allow more oil to flow to the pipe

FURTHER READING
How oil is used in the United States

Optimum home energy efficiency

Enhanced oil recovery and a view of possible sources for increased north american oil production, which does not yet count the Bakken oil

Bakken oil is currently about 100,000 barrels per day and seems to be heading to 250,000 barrels per day by the end of 2008. It could take 4-6 years to get a million or two million barrels per day. So it will take time to develop the fields and get the pipelines and other infrastructure. A continued build up of oilsand oil, the Gulf of Mexico oil and continued increase in biofuels. Shifting the US off of non-North American oil imports is still a big job even with the Bakken oil. However, it could be part of a substantial shift and allow more time for the development of more nuclear and other power sources and for more efficiency from thermoelectrics, ultracapacitor/battery hybrid and electric vehicles.

An informative 2006 analysis of the Bakken oil formation.


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7 comments:

kurt said...

This is what happens when we start to "run out" of oil. More oil is discovered.

We started running out of Pennsylvania crude in the 1920s. Everyone shouted doom and gloom. Then the Texas oil fields were discovered.

Same thing happened in the late 40's to early 50's. Then the middle-eastern oil was discovered.

The "shortage" in the 70's was caused mainly by government regulation of the industry, particularly pricing. When the industry was deregulated, first under Carter and later Reagan, prices started coming down.

The 70's was also when much of the African oil (Nigeria, Angola) was found and the advanced oil recovery technology was developed during this time.

The process repeats itself again in this decade.

Oil reserves oscillate between 10 to 17 years. When the reserves go below 10 years, the oil companies spend more money in exploration and find more oil. When the reserves exceed 17 years, the bean counters who run the oil companies cut back on exploration, because it is not an efficient use of shareholder capital.

Common sense suggests that developing hydrocarbon fuels from a renewable source is a good idea. This is where the recent work in synthetic biology comes in. Synthetic biology will lead first to designer algae for making hydrocarbon fuels, which will be far more efficient than this agricultural bio-fuels stuff being peddled by the liberal-left.

The next step in synthetic biology will be to make the actual hydrocarbon production chemistry without the rest of the cellular processes that make up the algae. This will be even more efficient.

Brian said...

Even being to pull 100 billion barrels out of this at 13 million barrels per day would be enough to allow the USA/Canada to be self sufficient in oil for 20 years. It would be enough time for a nice transition to electrification and the synthetic biology enabled biofuels you mentioned. So hopefully this would be the last oil that is needed.

The existing wells should be pulling 1 million barrels per day by the end of this year.

Al Fin said...

Manpower shortages will drive the economics of energy for the next few decades.

The advantage will eventually go to algal biodiesel/biobutanol and biosynthetis--because those processes are more economically automated than the rough world of producing sweet crude, heavy oils, and oil shale / tar sands. Yes, I know robots are supposed to start running offshore rigs, but my near-term bets are on humans for their ability to adapt to changing circumstances.

Cary said...

No amount of found reserves is ever going to be enough. Why? Mathematics. What most people don't understand is the idea of exponential growth and what that means in time. Exponential growth is what allows you to sock 15,000 a year aside in a 401K earning 10% (exponential growth) to end up with 4 million, not 450,000.

To help those who "buy" the idea of reserves for 20 years . . . let's use this example.

A single bacterium is in a bottle. Every minute it doubles - 50% minute-over-minute growth (instead of year-over-year to speed things up).

Start the clock running at 12:00 AM. By 1:00 AM, the bacterium still have lots of room. No Problem. By 5:00 PM, still, lots of room. But at what time does the bacterium realize that they're in trouble? 11:59 AM, before they do their last doubling and go from 50% full to 100% full.

But hey, one little bacterium builds a spaceship and finds 3 whole empty bottles! Yay, we're saved. But how much time does that REALLY buy them? 2 whole minutes. The first minute they double and fill one new bottle. The next minute, the other two.

We are at 11:59 PM and 58 seconds. With consumption growth as it is, there is no amount of reserve that is going to buy us a whole lot-o-time.

Cary said...

Brian, learn to do math before stating 100 billion = 20 years.

Global consumption is at 30 Billion barrels a year (USGS statistic). Factor in just 10% growth in global consumption year over year. . .

Year 1 - 30 Billion
now multiply that by 1.1 (1 + .10)
Year 2 - 33 Billion
Year 3 - 36.3 Billion
Year 4 - 39.93 Billion.

4 Years and the world has consumed Brian's 20 years worth of 100 Billion barrels.

Keep the math going . . .
Year 5 - 43.923 Billion
Year 6 - 48.31 Billion
Year 7 - 53.1 Billion
Year 8 - 58.46 Billion
Year 9 - 64.3 Billion
Total Barrels used - 407.3 Billion

All dried up. Went quick huh?

Anonymous said...

Cary:
"Brian, learn to do math before stating 100 billion = 20 years."

Cary, learn to read before criticizing someones math. He said U.S. Canada self sufficient in oil. In other words substitute for imports not provide the entire world with oil.

Cary: "
Factor in just 10% growth in global consumption year over year. . ."

Long term growth in world oil consumption has averaged 1.55 for the last 25 years.

Alan

Anonymous said...

w.r.t exponential growth - that arguments have been used wrongly for years - over population, AIDS, potable water, etc, etc. changes in human behavior and technology always avert the geometric disasters.