description essay
TRANSCRIPT
Hydraulic Fracturing Fluids By Amanda Murphy
Introduction Hydraulic fracturing (fracking) fluids have become a subject of debate in the United States
especially after the discovery of the Marcellus Shale One topic of concern is the treatment and
disposal of the flowback fluids (fluid that returns to the surface with extracted gas) A fracking
fluid is pressurized during drilling and injecting in order to fracture shale rocks to release natural
gas (methane) from inside There are 2 main components to the fluid a mixture of water and
sand and other chemical additives (refer to Fig1)
Usage of Water Water and sand together make up over 99 of the fluid used during hydraulic fracturing Each
drill site requires about 3-5 million gallons of water per frack
Why Water
Water is accessible affordable and incompressible so it is the primary component of
fracking fluid
Where the Water Comes From
Over half of the water used for Marcellus Shale drilling comes from rivers creeks and
lakes in Pennsylvania The remaining water is purchased from municipalities by drilling
companies
Transportation
Water can then be transported to the drill site by truck or through temporary pipelines
installed underground
Figure 1
Who Regulates Water Usage
The Pennsylvania Department of Environmental Protection (DEP) in cooperation with
the Delaware River Basin Commission and the Susquehanna River Basin Commission
regulates water used for Marcellus Shale drilling in Pennsylvania As part of the permit
application process drilling companies must identify the water sources from which they
plan to obtain water and specify anticipated impacts Sources may include rivers streams
and lakes or municipalities and must be approved by the appropriate river basin
commission
Usage of Other Chemical Additives
Even though chemical additives represent a very small portion (approx 05) of hydraulic
fracturing fluids they serve several important purposes
1) Eliminate bacterial growth in the wellmdashbacteria can cause corrosion which could
impact the safety and integrity of the well
2) Prevent scale build-up in the well
3) Reduce friction to help manage well pressure
Many of the additives are used in a wide variety of consumer products The following chart
shows the common chemicals in hydraulic fracturing fluids as well as how they are used in
everyday life
Figure 3
Figure 2 Well-Zoning and Structure In Pennsylvania gas wells cannot be drilled within
200 feet of structures water wells or freshwater
springs Moreover they cannot be drilled within
100 feet of streams or wetlands Waivers allow
companies to drill inside of these limits with
additional protective measures About 34 of US
public water supply comes from groundwater
sources while the rest comes from surface water
bodies like lakes rivers and reservoirs Municipal
wells work like residential wells but typically have
a larger diameter and higher flow rate Residential
water wells (Fig 2) reach an average depth of
about 200 feet but occasionally can reach depths
of more than 500 feet
After Water Has Been Used for Fracking Approximately 10-30 percent of the total water used per frack returns to the surface with the
extracted gas The remaining water remains deep underground It is mostly absorbed by the shale
formation which is isolated from the water table (depth below which all of the pore spaces and
sediments are completely saturated with water)
Flowback Flowback is the fluid that returns
to the surface with the extracted
gas It may contain salts clay
rock particles naturally
occurring elements dissolved
from the rock and chemicals
that were added prior to the
beginning of the hydraulic
fracturing process Most
flowback occurs within 7-10
days of drilling but may occur
for 3-4 weeks Flowback is
captured in lined pits or metal
tanks (refer to Fig 3) and must
be treated and reused at another
drill site or transported by truck
(refer to Fig 3) for proper disposal
How Flowback Becomes Contaminated There are 3 ways flowback water can become contaminated during Marcellus Shale drilling
Inadequate Water Management Plans
Companies are expected to follow Best Management Practices (BMPs) for storm water
management but if BMPs are not followed surface water containing silt and debris may
run off the site and into local waterways This type of contamination consists primarily of
mud
Surface Spills
Chemicals or chemical-laden fluids (flowback) may spill or leak and seep into the ground
surrounding a drill pad Fuel spills (gasoline diesel) from vehicles and equipment are
another source of potential contamination These types of spills can be identified due to
the distinct chemical ldquofingerprintrdquo of the spilled fluids While spills of this type have
been reported by the DEP and some investigations are ongoing there have not been any
substantiated cases of these fluids entering the groundwater supply
Methane Migration
Naturally occurring methane could potentially make its way into the groundwater supply
and enter private wells drilled into the aquifer The DEP has issued fines to gas
companies for methane migration although it is difficult to determine where the methane
originated and whether it can be tied to Marcellus Shale drilling
Flowback Regulation As a part of the permit application process drilling companies must identify where wastewater
or flowback will be treated and stored Additionally companies must adhere to the guidelines
provided by the Pennsylvania Department of Environmental Protection for water disposal The
DEP dictates that flowback must be treated to have a total dissolved solids (TDS) concentration
of 500 parts per million (ppm) or less for discharge into surface water bodies
Conclusion Hydraulic fracturing fluids are going to remain a controversial societal topic until further
research is conducted For now the Environmental Protection Agency and the DEP are doing
the best they can to mandate regulations
Sources
-Figure 1 was edited from httpnaturalgasorgwpcontentuploads201309shaleshock2jpg
-Figure 2 was edited from httpmcleodwaterwellscomimageswater_wells_drilledjpg
-Figure 3 was taken and edited from httpwellsite-dscomp=2164
- The chart was edited from
httpwwwintellectualtakeoutorgsiteswwwintellectualtakeoutorgfilesimagecachechart_cont
entchart-graphFracking-fluid-components5B15Dpng
-All technical information was taken from lectures from Dr Richard Parizek GEOSC 452
Hydrogeology Fall 2013
Who Regulates Water Usage
The Pennsylvania Department of Environmental Protection (DEP) in cooperation with
the Delaware River Basin Commission and the Susquehanna River Basin Commission
regulates water used for Marcellus Shale drilling in Pennsylvania As part of the permit
application process drilling companies must identify the water sources from which they
plan to obtain water and specify anticipated impacts Sources may include rivers streams
and lakes or municipalities and must be approved by the appropriate river basin
commission
Usage of Other Chemical Additives
Even though chemical additives represent a very small portion (approx 05) of hydraulic
fracturing fluids they serve several important purposes
1) Eliminate bacterial growth in the wellmdashbacteria can cause corrosion which could
impact the safety and integrity of the well
2) Prevent scale build-up in the well
3) Reduce friction to help manage well pressure
Many of the additives are used in a wide variety of consumer products The following chart
shows the common chemicals in hydraulic fracturing fluids as well as how they are used in
everyday life
Figure 3
Figure 2 Well-Zoning and Structure In Pennsylvania gas wells cannot be drilled within
200 feet of structures water wells or freshwater
springs Moreover they cannot be drilled within
100 feet of streams or wetlands Waivers allow
companies to drill inside of these limits with
additional protective measures About 34 of US
public water supply comes from groundwater
sources while the rest comes from surface water
bodies like lakes rivers and reservoirs Municipal
wells work like residential wells but typically have
a larger diameter and higher flow rate Residential
water wells (Fig 2) reach an average depth of
about 200 feet but occasionally can reach depths
of more than 500 feet
After Water Has Been Used for Fracking Approximately 10-30 percent of the total water used per frack returns to the surface with the
extracted gas The remaining water remains deep underground It is mostly absorbed by the shale
formation which is isolated from the water table (depth below which all of the pore spaces and
sediments are completely saturated with water)
Flowback Flowback is the fluid that returns
to the surface with the extracted
gas It may contain salts clay
rock particles naturally
occurring elements dissolved
from the rock and chemicals
that were added prior to the
beginning of the hydraulic
fracturing process Most
flowback occurs within 7-10
days of drilling but may occur
for 3-4 weeks Flowback is
captured in lined pits or metal
tanks (refer to Fig 3) and must
be treated and reused at another
drill site or transported by truck
(refer to Fig 3) for proper disposal
How Flowback Becomes Contaminated There are 3 ways flowback water can become contaminated during Marcellus Shale drilling
Inadequate Water Management Plans
Companies are expected to follow Best Management Practices (BMPs) for storm water
management but if BMPs are not followed surface water containing silt and debris may
run off the site and into local waterways This type of contamination consists primarily of
mud
Surface Spills
Chemicals or chemical-laden fluids (flowback) may spill or leak and seep into the ground
surrounding a drill pad Fuel spills (gasoline diesel) from vehicles and equipment are
another source of potential contamination These types of spills can be identified due to
the distinct chemical ldquofingerprintrdquo of the spilled fluids While spills of this type have
been reported by the DEP and some investigations are ongoing there have not been any
substantiated cases of these fluids entering the groundwater supply
Methane Migration
Naturally occurring methane could potentially make its way into the groundwater supply
and enter private wells drilled into the aquifer The DEP has issued fines to gas
companies for methane migration although it is difficult to determine where the methane
originated and whether it can be tied to Marcellus Shale drilling
Flowback Regulation As a part of the permit application process drilling companies must identify where wastewater
or flowback will be treated and stored Additionally companies must adhere to the guidelines
provided by the Pennsylvania Department of Environmental Protection for water disposal The
DEP dictates that flowback must be treated to have a total dissolved solids (TDS) concentration
of 500 parts per million (ppm) or less for discharge into surface water bodies
Conclusion Hydraulic fracturing fluids are going to remain a controversial societal topic until further
research is conducted For now the Environmental Protection Agency and the DEP are doing
the best they can to mandate regulations
Sources
-Figure 1 was edited from httpnaturalgasorgwpcontentuploads201309shaleshock2jpg
-Figure 2 was edited from httpmcleodwaterwellscomimageswater_wells_drilledjpg
-Figure 3 was taken and edited from httpwellsite-dscomp=2164
- The chart was edited from
httpwwwintellectualtakeoutorgsiteswwwintellectualtakeoutorgfilesimagecachechart_cont
entchart-graphFracking-fluid-components5B15Dpng
-All technical information was taken from lectures from Dr Richard Parizek GEOSC 452
Hydrogeology Fall 2013
Figure 3
Figure 2 Well-Zoning and Structure In Pennsylvania gas wells cannot be drilled within
200 feet of structures water wells or freshwater
springs Moreover they cannot be drilled within
100 feet of streams or wetlands Waivers allow
companies to drill inside of these limits with
additional protective measures About 34 of US
public water supply comes from groundwater
sources while the rest comes from surface water
bodies like lakes rivers and reservoirs Municipal
wells work like residential wells but typically have
a larger diameter and higher flow rate Residential
water wells (Fig 2) reach an average depth of
about 200 feet but occasionally can reach depths
of more than 500 feet
After Water Has Been Used for Fracking Approximately 10-30 percent of the total water used per frack returns to the surface with the
extracted gas The remaining water remains deep underground It is mostly absorbed by the shale
formation which is isolated from the water table (depth below which all of the pore spaces and
sediments are completely saturated with water)
Flowback Flowback is the fluid that returns
to the surface with the extracted
gas It may contain salts clay
rock particles naturally
occurring elements dissolved
from the rock and chemicals
that were added prior to the
beginning of the hydraulic
fracturing process Most
flowback occurs within 7-10
days of drilling but may occur
for 3-4 weeks Flowback is
captured in lined pits or metal
tanks (refer to Fig 3) and must
be treated and reused at another
drill site or transported by truck
(refer to Fig 3) for proper disposal
How Flowback Becomes Contaminated There are 3 ways flowback water can become contaminated during Marcellus Shale drilling
Inadequate Water Management Plans
Companies are expected to follow Best Management Practices (BMPs) for storm water
management but if BMPs are not followed surface water containing silt and debris may
run off the site and into local waterways This type of contamination consists primarily of
mud
Surface Spills
Chemicals or chemical-laden fluids (flowback) may spill or leak and seep into the ground
surrounding a drill pad Fuel spills (gasoline diesel) from vehicles and equipment are
another source of potential contamination These types of spills can be identified due to
the distinct chemical ldquofingerprintrdquo of the spilled fluids While spills of this type have
been reported by the DEP and some investigations are ongoing there have not been any
substantiated cases of these fluids entering the groundwater supply
Methane Migration
Naturally occurring methane could potentially make its way into the groundwater supply
and enter private wells drilled into the aquifer The DEP has issued fines to gas
companies for methane migration although it is difficult to determine where the methane
originated and whether it can be tied to Marcellus Shale drilling
Flowback Regulation As a part of the permit application process drilling companies must identify where wastewater
or flowback will be treated and stored Additionally companies must adhere to the guidelines
provided by the Pennsylvania Department of Environmental Protection for water disposal The
DEP dictates that flowback must be treated to have a total dissolved solids (TDS) concentration
of 500 parts per million (ppm) or less for discharge into surface water bodies
Conclusion Hydraulic fracturing fluids are going to remain a controversial societal topic until further
research is conducted For now the Environmental Protection Agency and the DEP are doing
the best they can to mandate regulations
Sources
-Figure 1 was edited from httpnaturalgasorgwpcontentuploads201309shaleshock2jpg
-Figure 2 was edited from httpmcleodwaterwellscomimageswater_wells_drilledjpg
-Figure 3 was taken and edited from httpwellsite-dscomp=2164
- The chart was edited from
httpwwwintellectualtakeoutorgsiteswwwintellectualtakeoutorgfilesimagecachechart_cont
entchart-graphFracking-fluid-components5B15Dpng
-All technical information was taken from lectures from Dr Richard Parizek GEOSC 452
Hydrogeology Fall 2013
How Flowback Becomes Contaminated There are 3 ways flowback water can become contaminated during Marcellus Shale drilling
Inadequate Water Management Plans
Companies are expected to follow Best Management Practices (BMPs) for storm water
management but if BMPs are not followed surface water containing silt and debris may
run off the site and into local waterways This type of contamination consists primarily of
mud
Surface Spills
Chemicals or chemical-laden fluids (flowback) may spill or leak and seep into the ground
surrounding a drill pad Fuel spills (gasoline diesel) from vehicles and equipment are
another source of potential contamination These types of spills can be identified due to
the distinct chemical ldquofingerprintrdquo of the spilled fluids While spills of this type have
been reported by the DEP and some investigations are ongoing there have not been any
substantiated cases of these fluids entering the groundwater supply
Methane Migration
Naturally occurring methane could potentially make its way into the groundwater supply
and enter private wells drilled into the aquifer The DEP has issued fines to gas
companies for methane migration although it is difficult to determine where the methane
originated and whether it can be tied to Marcellus Shale drilling
Flowback Regulation As a part of the permit application process drilling companies must identify where wastewater
or flowback will be treated and stored Additionally companies must adhere to the guidelines
provided by the Pennsylvania Department of Environmental Protection for water disposal The
DEP dictates that flowback must be treated to have a total dissolved solids (TDS) concentration
of 500 parts per million (ppm) or less for discharge into surface water bodies
Conclusion Hydraulic fracturing fluids are going to remain a controversial societal topic until further
research is conducted For now the Environmental Protection Agency and the DEP are doing
the best they can to mandate regulations
Sources
-Figure 1 was edited from httpnaturalgasorgwpcontentuploads201309shaleshock2jpg
-Figure 2 was edited from httpmcleodwaterwellscomimageswater_wells_drilledjpg
-Figure 3 was taken and edited from httpwellsite-dscomp=2164
- The chart was edited from
httpwwwintellectualtakeoutorgsiteswwwintellectualtakeoutorgfilesimagecachechart_cont
entchart-graphFracking-fluid-components5B15Dpng
-All technical information was taken from lectures from Dr Richard Parizek GEOSC 452
Hydrogeology Fall 2013