Transcript Document

Chemical Characteristics
of Frac Flowback Water &
Technologies Deployed to
Recycle Water, Reduce
Waste Volumes & Reduce
Cost
Patrick Blau
Special Projects Mgr
Chemical Engineering
Tervita Manages Waste
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Tervita Facilities
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Water Supply & Use
• Oil and gas sector:
• A small user of water
relative to other segments
• A large recipient of
attention and regulatory
scrutiny
• Industry’s water
management critical to
social license
Percentage of Water Used by
Market Segment in the U.S.
Industrial,
5%
Domestic,
1%
Aquaculture,
2%
Thermoelect
ric Power,
41%
Irrigation,
37%
Public
Supply,
12%
Livestock, 1%
Mining and
Oil & Gas, 1%
Source: USGS
Cubic meters used in Alberta
• Regulations continue to
tighten on industry & limit
access
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Produced Water Volumes O & G
• Produced water volumes predicted to increase by 32% by 2025*
• Potential for water reuse exists to decrease freshwater use
• Produced water management is a major cost to industry and
consumes resources otherwise slated for hydrocarbon production
USA
21 billion
bbl/yr
Other states 20%
Texas
35%
70 billion bbl/yr
Worldwide produced
water volume
(2007)
Rest of the world
49 billion bbl/yr
California
12%
USA 21 billion bbl/yr
Produced
water volume
(2007)
Louisiana 5%
Wyoming
11%
Oklahoma 11%
Kansas
6%
* Source: Clarke &
Veil, 2009
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Addressing Environmental Concerns
of Hydraulic Fracturing
• There has been a significant increase in fracking:
• Between 2004-2009 US shale gas supply increased 5 times
• In Canada, shale gas currently accounts for nearly 30% of
natural gas production
• This has led to concerns/perceptions about:
• Aquifer and soil contamination
• Unsustainable water use
• Seismic activity
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What The Frac?
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Typical Horizontal Shale Well and Frac
Aquifers are typically at much shallower depths
than shale gas zones
Well constructed wellbore and casing prevent
upward migration of frac fluid and produced water
• Old, poorly constructed existing vertical wells
are a potential contamination risk during
fracking
• Pressure characteristics within
the geology determine the
extent to which vertical
fracturing may exist
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Fracs and Aquifer Contamination
• Pay zone frac typically separated from aquifers by
thousands of feet and several impermeable layers,
vertical frac propagation typically < 300 ft
• Historic Data – Oilfield contamination issues, where it
has occurred, focused on surface operations and
historic oil/gas wells in the area. Not Frac related.
• Presence of methane in drinking water wells, where
observed, is associated with naturals sources. Not
associated with recent drilling.
• Disclosure and understanding of additives is helpful and
adds transparency for the public.
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Incidents Investigated and Determined
Cause of Problem (Kell, 2011)
Source: King 2012. Estimating Frac Risk and Improving Frac Performance in Unconventional Gas and Oil Wells.
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Aquifer and Soil Contamination
Leading Practices for Risk Mitigation
• Baseline aquifer data assessment allows accurate
monitoring and real-time adjustment
• Comprehensive environment and geology assessment
facilitate effective frac planning
• Pad development for drilling minimizes surface impact
• Improved frac and produced water storage and
treatment minimize contamination risk
• Improved isolation through cement additives
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Understanding Additives
Source: http://fracfocus.org/water-protection/drilling-usage
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Chemicals Commonly Used in Shale
Fracturing and Consequences of Not Using
the Chemical
Source: http://gekengineering.com/Downloads/Free_Downloads/A_Guide_to_Chemicals_in_Fracturing_10_Aug_2010.pdf
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How Much Chemical is Used?
Source: http://gekengineering.com/Downloads/Free_Downloads/A_Guide_to_Chemicals_in_Fracturing_10_Aug_2010.pdf
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Sustainable Water Use
Leading Practices for Risk Mitigation
• Re-use of fluids during drilling.
• Tervita “Closed Loop” systems treat and enable the reuse of drilling fluids.
• Treatment of flowback and produced water
• Tervita water treatment technologies minimize
environmental impact
• Understanding resource availability
• Brackish water can be treated for use to minimize
freshwater use
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Frac Water Example
• A typical frac may require 10 to
20,000 m3 of water1
• This recovers about 11,000 person
years of energy2
• Typical 100,000 ppm TDS
Flowback concentration with
variable non-carbonate and
carbonate hardness depending on
region
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Closed Loop Drilling
WELL
DRILLING FLUIDS
Rig Equipment
FLUID MAKE UP TANK
Tervita Equipment
CUTTINGS
RIG SHAKERS
UNDERFLOW
RIG TANK S
RIG TANK S
CENTRIFUGE FEED
Chemical Injection System
DRYING SHAKER
UNDERFLOW
POLYMER
CENTRIFUGE (High G)
SOLIDS BINS
CENTRATE
SOLIDS
Control Cabin & Laboratory
Centrifuge
Mixing
Tank
Chemical
Injection
System
Chemistry of Frac Flowback Water
Shale Fracturing Flowback Water
Chemistry
(Various North American Basins)
1000000
100000
Log(ppm)
10000
1000
100
10
1
AVE
MIN
MAX
Sources: Canadian Shale Basins, Bakken, Haynesville, Marcellus, Barnet flowback water chemical analysis
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Tervita Mobile Water Treatment
Softened H2O
H2O In
Stablflote ®
Portable RO Unit
(optional)
Clarifier
Centrifuge
VRU (Vertical Reactor Unit)
Centrate Re-Cycle
Dry Solids Out
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Haynesville Water
Flowback
Water
Raw Water
In
Product
Water
10,200
40
3,780
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Barium (ppm)
1,050
1
Strontium (ppm)
72
1
Magnesium (ppm)
178
ND
Iron (ppm)
93
0.3
Total Hardness
(ppm)
Calcium (ppm)
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Seismic Activity
Leading Practices for Risk Mitigation
• Assessment of fault location to minimize fault risk during
frac planning
• Reduce frac flowback and produced water disposal to
minimize seismic activity related to disposal caverns
• Careful monitoring to minimize risk
• Pressure monitoring
• Frac propagation monitoring
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Increasing Industry Response
• The industry is responding to growing awareness around
impacts and mitigating strategies
• CAPP together with industry partners established newly
created Guiding Principles and Operating Practices for
Hydraulic Fracturing
• Guidelines impact:
• Use and disclosure of frac fluid additives, groundwater
testing, wellbore construction quality, water sourcing,
fluid management
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Additional Resource Utilization
• Collaboration with Oil & Gas operators to identify
valuable fluid streams previously deemed as
waste.
1. At the Drilling Site
• a. Extending the material life.
• b. “Upgrading” to lower disposal cost option.
2. At the TRD Processing Plant
Examples: Saltwater/ Calcium Chloride Brines
3. Backhaul Savings.
Private & Confidential
July-16-15
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Questions or Comments?
Pat Blau
(701)-577-4001
[email protected]
or
Preston McEachern
Director, Research and Development
Tervita Corporation
(403) 718-1266
[email protected]
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