American Oil and Gas Reporter - November 2018 - 104

SpecialReport: A&D and Startups

At its pilot plant in St. Albans, W.V., Clean Water LLC says it has confirmed that its proprietary technology can extract valuable salts from produced water while preparing the
water for reuse or discharge. The producer-backed company describes its technology
as affordable and profitable enough to offer a compelling alternative to underground injection wells, especially in areas where regulators are limiting injection volumes.

which sometimes lose 2-3 percent of the
oil volume during treatment as some of
the lights are stripped out."
Devries says RevEnergy plans to operate its treatment skids for clients in exchange for volume-based monthly fees,
a model that reduces the client's upfront
capital costs. The exact cost will vary
based on the quality and quantity of the
oil that needs to be treated, he says,
noting that heavier oils take longer to
process.
"Usually, the system would be deployed
at a central tank battery or processing facility," Devries comments. "The economics
can make sense at volumes below 1,000
barrels of oil a day, but we would not
want to put a system on an individual
well that is only 100 bbl/d."
Simulations and lab tests suggest that
the process will be suitable for oil from
every major U.S. play, Devries reports.
He says the company is looking for partners to do field tests.
Disposal Well Alternative
In Oklahoma, regulators have begun
limiting the amount of water that can be
injected into disposal wells in order to
prevent induced seismicity. As other states
consider similar limits, producers will
need a cost-effective way to treat produced

water so it can be reused or disposed of
at surface, says Tim Wilcox, the managing
member of Clean Water LLC.
Wilcox also heads Base Petroleum, a
West Virginia producer. He formed Clean
Water LLC with other producers and a
water treatment company to provide a
patented technology that extracts pure,
marketable salts from produced water.
The company has built a 3,000 bbl/d
pilot plant. According to Wilcox, the
plant has confirmed lab tests showing
that the technology turns pretreated produced water into three revenue streams:
calcium chloride that is 94 percent pure,
sodium chloride that is 99 percent pure,
and distilled water with total dissolved
solids below 150 parts per million.
The sodium chloride can be used on
roads, while the calcium chloride can
be reused in water-based drilling fluids
or chlorine production, Wilcox says. "As
a rule of thumb, the sodium chloride
has a value of $0.02 per pound, while
the calcium chloride is worth $0.12$0.15/pound," Wilcox offers. "The distilled water can be concentrated and
reused in fracturing operations or sold
to power plants and other facilities for
use a coolant."
Extracting salt from water is nothing
new, acknowledges Tony Anderson, Clean

104 THE AMERICAN OIL & GAS REPORTER

Water's chief technologist. "In fact, we
developed the technology after trying a
more common approach that involves using evaporation to cause the salts to reach
equilibrium, fall out, and separate. This
works, but the salt tends to build up in
and plug the treatment system's piping.
"To limit plugging, we found a way
to separate the calcium and sodium chloride at room temperature within the water,"
he relates. "Once we have done that, we
can concentrate the calcium chloride into
a heavier solution and remove the water
from both salts through evaporation."
According to Anderson, this approach
reduces from four to one the number of
areas where salt can plug equipment.
"The remaining area is in a mixing tank,"
he notes. "We have not had not any plugging there in the pilot plant, and we do
not think any will occur under normal
conditions, but if it does happen, it's easy
to switch to a backup tank."
Anderson says eliminating plugging
should allow the plant to operate 24 hours
a day for at least 300 days a year. He
adds that the process can use plate-frame
heat exchangers rather than shell-andtube heat exchangers, greatly reducing
its space requirements and capital costs.
A plant capable of handling 3,000
bbl/d would cost $9 million-$11 million
to build in an area with utility power,
Wilcox calculates. "If the plant charges
$4 to treat each barrel and sells the salts
at reasonable prices, it would be able to
generate $5 million a year, giving it a
30-40 percent rate of return," he says.
That rate of return would be even
higher for plants with a larger capacity,
Wilcox notes. He says Clean Water envisions producers or service companies
building a network of 9,000-12,000 bbl/d
water treatment plants near wells in
order to reduce trucking or pipe construction costs. "This would also allow
producers to rotate water around during
maintenance periods, so we see it as the
most efficient way to leverage our technology," he comments.
r

Coming In December
Winter 2017-18 packed some surprise punches, including a cold snap
across much of the country that resulted in record New Year's Day demand. What does this winter have in
store? The December special reports
provides some of the answers.



American Oil and Gas Reporter - November 2018

Table of Contents for the Digital Edition of American Oil and Gas Reporter - November 2018

Contents
American Oil and Gas Reporter - November 2018 - Intro
American Oil and Gas Reporter - November 2018 - 1
American Oil and Gas Reporter - November 2018 - 2
American Oil and Gas Reporter - November 2018 - Contents
American Oil and Gas Reporter - November 2018 - 4
American Oil and Gas Reporter - November 2018 - 5
American Oil and Gas Reporter - November 2018 - 6
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