Site Visit Report

Eureka Resources, LLC

Marcellus Shale Gas Operations

February 25, 2012
i

TABLE OF CONTENTS

Page

1.0 INTRODUCTION .................................................................................................................1-1

2.0 BACKGROUND AND OBJECTIVES .......................................................................................2-1

3.0 OVERVIEW OF SHALE GAS EXTRACTION WASTEWATER TREATMENT ..............................3-1

3.1 Wastewater Services............................................................................................3-1

3.2 Plant Flow Description ........................................................................................3-2

3.3 Treated Wastewater Streams................................................................................3-8

3.4 Waste Streams......................................................................................................3-9

3.5 Costs...................................................................................................................3-10

APPENDIX A LIST OF PARTICIPANTS ON THE EUREKA SITE VISIT..........................................A-1

APPENDIX B POWER POINT PRESENTATION OF ALL SITE VISIT PICTURES .................B-ERROR!

BOOKMARK NOT DEFINED.

APPENDIX C PLANT FLOW DIAGRAM................................ C-ERROR! BOOKMARK NOT DEFINED.
ii

LIST OF FIGURES

Page

Figure 3-1. Plant Flow Diagram .................................................................................................. 3-3

Figure 3-2. Unloading and Screening Area ................................................................................. 3-5

Figure 3-3. Parallel Plate Clarifier............................................................................................... 3-5

Figure 3-4. Circular Clarifier....................................................................................................... 3-5

Figure 3-5. Eureka’s Nomad Evaporator Unit Flow Diagram..................................................... 3-7
iii

LIST OF TABLES

Page

Table 3-1. Eureka's Annual Wastewater Treatment Volume....................................................... 3-2

Table 3-2. Chemically Treated Wastewater Target Quality ........................................................ 3-9

Table 3-3. Eureka’s Wastewater Treatment Costs..................................................................... 3-10

Table 3-4. Eureka’s Operational Costs...................................................................................... 3-11
1-1

1.0 INTRODUCTION

On June 14, 2012, the U.S. Environmental Protection Agency (EPA) held a conference 

call with Eureka Resources, LLC (Eureka) to discuss their plant operation in Williamsport, 

Pennsylvania. On September 18, 2012, the EPA met with Eureka in Williamsport, Pennsylvania

located in the northern tier of the Marcellus. Discussion topics included:

 Wastewater Services

 Plant Flow Description

 Treated Wastewater Streams

 Waste Streams

 Costs

Site visit participants are listed below. Contact information is included in Appendix A.

U.S. EPA Office of Water, Office of Science and Technology Engineering and Analysis 

Division

Lisa Biddle

Tom Born

Brian D’Amico

Erik Helm

Pooja Parikh

Eastern Research Group, Inc. (ERG) (EPA Contractor)

Casey MacQueen

Brent Ruminski

Eureka Resources

Jerel Bogden

Dan Ertel

John Saton
2-1

2.0 BACKGROUND AND OBJECTIVES

The Eureka site visit was the fourth in a series of site visits that the EPA plans for this 

industry. The purpose of the Eureka site visit was to collect background information on the shale 

gas extraction wastewater treatment industry and observe wastewater treatment operations. To 

initiate site visits, the EPA reviewed information about Marcellus shale gas producers and their 

wastewater management practices. During this review, the EPA identified Eureka as a recipient 

of shale gas extraction wastewater for treatment, active in the Marcellus Shale Play.

John Staton, Jerel Bogden, and Dan Ertel and of Eureka led the discussion of the 

company’s Marcellus operations and the site tour. The remainder of this report summarizes 

information discussed during the June 14, 2012 conference call, September 17, 2012 site visit, 

and a February 7, 2013 follow up telephone conversation. After the follow up telephone 

conversation, Eureka provided the flow diagram presented in Appendix C.
3-1

3.0 OVERVIEW OF SHALE GAS EXTRACTION WASTEWATER TREATMENT

During the conference call and prior to a tour of Williamsport, Pennsylvania operations, 

the EPA and Eureka discussed general shale gas extraction wastewater treatment. Eureka 

provided an overview of shale gas extraction wastewater treatment. Topics discussed include:

 Wastewater Services

 Plant Flow Description

 Treated Wastewater Streams

 Waste Streams

 Costs

3.1 Wastewater Services

Eureka’s plant accepts shale gas wastewater from operators in northeastern Pennsylvania

and is the only centralized waste treater (CWT) permitted by the PA DEP to discharge to a 

publically owned treatment works (POTW). Eureka either returns treated wastewater to operators 

for reuse in drilling or hydraulic fracturing or discharge it to the Williamsport POTW. Eureka 

holds a General Permit (WMGR123NC005)

1

from PA DEP which allows them to accept all 

wastewaters from drilling, fracturing, and production. It also allows them to accept any 

wastewaters from compressor stations prior to commerce.2Eureka plans to expand their business

in the future by constructing three new plants throughout northern Pennsylvania.

Over the past several years, northern Pennsylvania operators have increasingly managed 

shale gas wastewater through reuse in fracturing or drilling activities. If the wastewater requires 

treatment prior to reuse, operators may treat it onsite or at available CWTs. At the time of the site

visit, Eureka estimated that 50 percent of operators that reuse wastewater send their wastewater 

offsite to CWTs for treatment in the Marcellus. Table 3-1 provides wastewater volume, number 

of operators, and number of wells served by Eureka between 2009 and June 2012 according to 

Pennsylvania Department of Environmental Protection’s (PA DEP) oil and gas database. Eureka 

has a customer base of 20 different shale gas operators from 18 counties. According to PA DEP 

data, only seven different customers have delivered wastewater to the plant in 2012 through 

June. Eureka estimated that most of their customers haul wastewater from wells within 120 miles 

of the Williamsport plant.

 

1 More information available online at: 

http://files.dep.state.pa.us/Waste/Bureau%20of%20Waste%20Management/WasteMgtPortalFiles/SolidWaste/Resid

ual_Waste/GP/WMGR123.pdf. 

2 Commerce is the point at which the gas is sold by the operator.
3-2

Table 3-1. Eureka's Annual Wastewater Treatment Volume

Year Volume of Wastewater (bbls)a Number of Operators Number of Wells Served

2009 292,964 2 48

2010 490,446 6 198

2011 747,770 14 286

2012 b248,450 7 325

Source: PA DEP’s Oil and Gas Reporting Database.

a—Includes flowback, produced water, and drilling fluid. 42 gallons equals 1 barrel.

b—2012 data is through June 30, 2012.

The company offers two main services:

 Disposal—Operators pay to drop off a load of wastewater for treatment and leave. 

Eureka either finds another operator to take the treated wastewater or discharges it 

to the Williamsport POTW.

 Recycling—Operators pay to drop off a load of wastewater and pick up a load of 

treated wastewater. They can choose from the following treatment levels:

 Chemical treatment—Wastewater goes through clarification and chemical 

precipitation to remove total suspended solids (TSS) and some metals. 

Operators commonly reuse this wastewater for hydraulic fracturing and 

drilling.

 Chemical treatment and evaporation/condensation—Wastewater goes 

through clarification, chemical precipitation, and 

evaporation/condensation to remove TSS, metals, and total dissolved 

solids (TDS) resulting in a distilled water product. Operators do not 

typically use distilled water for hydraulic fracturing, but may take this 

water if freshwater is in demand.

3.2 Plant Flow Description

The plant is permitted to treat 337,500 gallons per day (8,036 barrels per day) on a 

monthly average and has no daily maximum limit but has treatment capacity of 420,000 gallons 

per day (10,000 barrels per day). A typical throughput for the plant is 168,000 gallons per day

(4,000 barrels per day). Eureka’s discharge permit allows them to discharge a maximum 325,000

gallons per day (7,738 barrels per day) to the POTW. However, the monthly average discharge to 

the POTW must be less than 225,000 gallons per day (5,357 barrels per day).

Figure 3-1 presents a flow diagram of the overall treatment system. Figure 3-2 through

Figure 3-4 provide photos of individual units from the site visit. No photos of the filter press or 

evaporator were taken due to confidentiality. Appendix C includes a detailed plant flow diagram 

Eureka provided after the February 2013 follow up call.
3-3

Figure 3-1. Plant Flow Diagram

Treatment steps include:

 Screening—All fluids are unloaded into receiving tanks through basket strainers, 

sampled and graded based on pH, TDS, and TSS. Influent loads are categorized 

into two groups: low TSS (i.e., flowback and produced water) and high TSS (i.e., 

top hole3and drilling fluids). Eureka also monitors all incoming wastewater for 

radioactivity and rejects any wastewater load with radioactivity more than 10 

microrems per hour above background levels. Figure 3-2 shows the unloading 

area.

 

3

 Water that flows to the surface during the initial drilling process.

Sludge 

Dewatering

Solid waste to

landfill

Truck unloading 

area

Distillate

Storage

Evaporation 

Condensation

Truck pickup 

area 

Concentrated 

brine

Sludge

Returned to 

operator

Underground 

injection in 

Ohio

Chemically 

Treated 

Wastewater

Storage

Decant 

water

Primary 

Clarifier

Wastewater Stream

Waste Streams

Water Quality 

Monitoring 

Williamsport 

Distillate POTW

Receiving 

Tanks and 

Basket 

Strainer

Storage 

Tank

Storage 

Tank

Circular 

Clarifier 

Treatment 

Train (B)

Parallel 

Plate 

Clarifier 

Treatment 

Train (A)

Oil 

Collection

Tote
3-4

 Primary Clarification—The primary clarifier separates oils and solids from the 

wastewater. Oil is recovered and recycled. Each graded load flows to one of two 

sets of chemical treatment trains. Treatment train A has a 110 gallon per minute 

throughput equipped with a parallel plate clarifier while treatment train B has a 

240 gallon per minute throughput equipped with a large circular clarifier. 

Although treatment train B is capable of treating higher TSS wastewater, Eureka 

often switches high and low TSS loads between the two treatment trains 

depending on the influent volumes of each load type per day. 

 Clarification—Each clarification treatment train contains pH adjustment tanks, 

flash mixer, clarifier, and equalization tank. If the treated wastewater does not 

meet the quality targets after equalization it is routed back to the storage tank. 

Figure 3-3 and 3-4 show the parallel plate and large circular clarifiers,

respectively.

 Evaporation/Condensation—Chemically treated wastewater flows from the 

clarifiers to either the chemically treated wastewater storage tanks for reuse or the

Nomad evaporator unit. The evaporator unit generates concentrated brine and 

distilled water. The concentrated brine is hauled to Ohio underground injection 

wells or returned to the operator for reuse. The distillate is stored until an operator 

picks it up for reuse or discharged to a sewer line that runs to the Williamsport 

POTW.

 Treated Wastewater and Distillate Storage—Chemically treated wastewater and 

distillate are stored in separate tanks until an operator picks it up for reuse.

Alternatively, distillate may be routed directly to the POTW via sewer line.

 Solids Handling—Tank bottoms from the clarifiers flow to a rotary filter press

which generates solid waste and water. The solid waste is hauled to a landfill. 

Water is routed back to the headworks.
3-5

Figure 3-2. Unloading and Screening Area

Figure 3-3. Parallel Plate Clarifier

Figure 3-4. Circular Clarifier
3-6

Eureka’s plant is equipped with a Fountain Quail evaporation/condensation unit called 

the Nomad. This unit uses mechanical vapor recompression (MVR) technology to convert high 

TDS wastewater into concentrated brine and treated wastewater called distillate. The percentage 

of distillate recovered is inversely proportional to the influent TDS concentration, as illustrated 

through Equation 1.

4

 

For example, the typical shale gas wastewater delivered to Eureka has a TDS 

concentration of 100,000. Using the above equation, this results in a 60 percent distillate 

recovery. The 2012 cumulative average recovery was 62 percent. TDS concentrations higher

than approximately 125,000 will result in lower than 50 percent recovery. At TDS concentrations 

of 250,000 mg/L, recovery is approximately zero. Eureka explained it is not practical to 

evaporate wastewater with such high TDS.

Figure 3-5 shows a flow diagram of the Nomad unit. The steps include:

1. Influent wastewater is preheated through a series of cross-flow heat exchangers.

Energy is transferred from the downstream concentrated brine, distillate, and 

compressed water vapor to the influent wastewater.

2. The wastewater enters the main vessel. During startup and before there is flow 

through the downstream heat exchangers, the wastewater is not preheated; it is 

heated in the main vessel by steam from a 35 horsepower natural gas boiler. The

boiler only runs approximately two percent of the total operational time. During 

startup and steady state operation, the surface of the wastewater reaches 

approximately 212 degrees Fahrenheit at atmospheric pressure and evaporates. 

Pollutants remain in the wastewater, resulting in concentrated brine.

3. The water vapor in the boiler is vented to a mechanical compressor. The 

compressor increases temperature and pressure of the vapor to 235 degrees 

Fahrenheit and 22 to 24 pounds per square inch (psia).

4. The compressed water vapor expands across the main heat exchanger where its 

latent heat of condensation5is transferred to influent wastewater. At this point, the 

wastewater becomes condensed wastewater (i.e., distillate) at 212 degrees 

Fahrenheit.

5. The distillate flows through a series of additional heat exchangers where it 

provides sensible heat6to preheat influent wastewater.

 

4 Equation derived from EPA’s Proceedings of the Technical Workshops for the Hydraulic Fracturing Study: Water 

Resources Management. 600/R-11/048. May 2011 Available online at: 

http://www.epa.gov/hfstudy/HF_Workshop_4_Proceedings_FINAL_508.pdf.

5 Latent heat of condensation is the heat release by water vapor when it condenses from a gas to a liquid.

6

Sensible heat is the heat released or obtained by water during a change in temperature. 
3-7

Figure 3-5. Eureka’s Nomad Evaporator Unit Flow Diagram

During a February 2013 telephone conversation, Mr. Staton reported that Eureka was in 

the process of permitting and constructing a crystallization7unit as an add-on treatment option to 

their Williamsport plant.

8 When installed, the crystallizer will treat the concentrated brine from 

the evaporator and convert approximately 80 to 85 percent of it concentrated to distillate. . The 

sodium chloride crystals will be 98 to 99 percent pure. Eureka explained that they have not yet 

determined how salt crystals will be disposed of or sold for reuse, but options include:

 Hauled to landfill9;

 Returned to operators to use as an additive in drilling fluid10;

 Sold as deicing road salt; and

 

7 Crystallization is a treatment process that converts water containing high TDS concentrations into solid crystals

and distillate.

8 Eureka recently shipped a sample of Pennsylvania shale gas wastewater to Switzerland to test on an existing 

crystallizer.

9

 Because the water has been removed, transport and disposal of salt crystals is less expensive than transport and 

disposal of brine.

10 Salt may be used as an additive in drilling fluid to increase density and/or increase a fluids electrical conductivity.

Main 

Cross Heat 

Exchanger

Condensed 

wastewater 

(distillate)

Influent

wastewater

Main Vessel

Mechanical 

Compressor

Water vapor

Concentrated 

brine 

Preheated wastewater

Compressed 

water vapor 

Secondary 

Heat 

Exchanger

Condensed 

wastewater 

(distillate)

Startup

Boiler

Steam

Tertiary Heat 

Exchanger

Concentrated 

brine

Preheated wastewater
3-8

 Sold as an ingredient to an industrial process.

Eureka explained that the liquid purge stream contains calcium chloride at concentrations 

less than 35 percent. If the calcium chloride concentration is at least 35 percent, the purge stream 

would have high value for other industrial applications. As a result, Eureka is considering future

upgrades to the crystallization unit that would further concentrate the purge stream to increase

the calcium chloride concentration. In the mean time, Eureka explained that they their purge 

stream disposal and reuse options include:

 Hauled to underground injection well;

 Returned to operators to use as a drilling fluid additive11; and

Eureka conducted preliminary research for using the salt crystals as road salt. PA DEP’s

General Permit WMGR128 provides standards for salts generated at oil and gas waste facilities 

with a General Permit WMGR123 (Eureka’s current permit type) that are to be used for deicer or 

as an ingredient to other industrial processes.

12 This permit provides 21 specific quality standards 

for salt crystals including two radioactive constituents: Thorium 232 (2 pCi/kg) and Uranium 

238 (2 pCi/g). Eureka expects the salt crystals generated by their crystallizer to meet all of the

standards of the PA DEP WMGR128 permit.

Eureka estimated the crystallizer unit will cost approximately $7 million and will be 

capable of crystallizing 5,000 barrels per day. Eureka had the option between a 5,000 and 10,000 

barrel per day design but chose the smaller unit because it is capable of being moved to new 

locations. Expected cost to operators for this treatment will be $10.75 to $11.00 per barrel 

assuming the salts must be hauled to a landfill. In the event that the salt can be beneficially used 

by operators or as road salt, total cost may be as low as $7 per barrel to operators.

3.3 Treated Wastewater Streams

Two streams of treated wastewater leave the plant:

 Chemically Treated Wastewater — Picked up by operator for reuse in fracturing 

or drilling; and

 Distillate — Piped to Williamsport POTW or picked up by operator for reuse in 

shale gas activities.

Most commonly, operators tend to reuse chemically treated wastewater for hydraulic 

fracturing. Chemically treated wastewater contains approximately 100,000 mg/L TDS when it 

leaves the plant. Most operators mix this treated wastewater with freshwater prior to fracturing 

for a final TDS concentration of approximately 50,000 mg/L. Eureka monitors the chemically 

treated water to ensure the water quality meets the operator’s specifications. Specifications vary 

from operator to operator, but Table 3-2 lists some general target levels.

 

11 Salt may be used as an additive in drilling fluid to increase density and/or increase a fluids electrical conductivity.

12 PA DEP Permit 128 guidance is available online at: 

http://files.dep.state.pa.us/Waste/Bureau%20of%20Waste%20Management/WasteMgtPortalFiles/SolidWaste/Resid

ual_Waste/GP/WMGR128.pdf. 
3-9

Table 3-2. Chemically Treated Wastewater Target Quality

Constituent Approximate Concentration or Range (mg/L)

TDS 100,000

TSS < 50

Sulfate Non Detect

pH 5 to 8 S.U.

Eureka explained that operators do not typically specify quality criteria for barium and 

strontium, especially if they are reusing the water for drilling fluid. This is because barium is a 

component of barite, which is a common additive for drilling fluid that increases density. If 

treated drilling fluid has higher barium concentration, then the operator can reduce costs by 

purchasing less barite additive.

Distillate from the evaporation/condensation unit contains less than 10 mg/L TDS as well 

as trace amounts of ammonia and light organics (e.g., ethanol).13 Distillate is not typically used 

for hydraulic fracturing operations; however, operators will use distillate as a freshwater source 

if weather has been dry and freshwater is in demand. Operators can also use distillate for 

miscellaneous shale gas activities, such as rig cleaning and cementing. If operators do not have a 

need for distilled water, Eureka indirectly discharges the water through the Williamsport POTW. 

Eureka conducts the following monitoring on the discharge to the POTW:

 Daily monitoring for TDS and pH.

 Monthly monitoring for biochemical oxygen demand (BOD), chemical oxygen 

demand (COD), and organic parameters regulated under 40 CFR 437 Organics 

Subcategory C.

14

 Annual monitoring for priority pollutants.

3.4 Waste Streams

Two waste streams leave the plant:

 Concentrated brine—Trucked to Ohio for underground injection or picked up by 

operator for reuse; and

 Solid waste—Trucked to landfill. Eureka estimated that when the plant is running 

at typical capacity (4,000 barrels per day), it generates 10 to 30 tons per day of 

solid waste.

Concentrated brine is either trucked to Ohio for underground injection or given back to 

the operators. The brine has a TDS concentration around 250,000 mg/L. Eureka explained that 

there are a few injection wells in Pennsylvania but they are owned by operators and have 

relatively low capacities. In Ohio, there are almost 200 injection wells. Ohio injection well 

operators charge approximately $2.5 to $4.5 per barrel for disposal for heavier brine (i.e., 

concentrated brine from evaporator). For less dense fluid (i.e., flowback), this cost may be as 

 

13 Pollutants that have a lower boiling temperature than water will likely be present in the distillate at trace levels. 

14 Available online at: http://ecfr.gpoaccess.gov/cgi/t/text/textidx?c=ecfr&rgn=div5&view=text&node=40:30.0.1.1.13&idno=40#40:30.0.1.1.13.3.4.1 . 
3-10

high as $3.8 to $6.75 per barrel. Injection operators may surcharge for excessive TSS

concentrations. These disposal fees are in addition to trucking, which costs Eureka $9 to $13 per 

barrel. Eureka pays for trucking on a contract basis.

Because trucking this waste stream to Ohio is expensive, Eureka offers it to operators for 

a credit on their account. Operators may have use for concentrated brine during the drilling 

process when high density fluids are desired or in cold weather as an anti-freezing agent. During 

winter months, Eureka does not haul any brine to Ohio because the operators reuse it all. Eureka 

is not required to monitor the brine for any constituents, but voluntarily monitors the brine to 

evaluate the evaporator’s performance and to study the potential performance of a crystallizer 

unit.

Solid waste is hauled to a landfill that is PA DEP-approved for handling non-hazardous 

oil and gas solid waste. Eureka screens each load for radioactivity using a Geiger counter before 

it leaves their site. If they detect radioactivity levels more than 10 micorems per hour above 

background level, they immediately quarantine the load and notify PA DEP. Eureka stated that 

they eventually would ship the quarantined solid waste to the landfill where it would be retested 

to verify the radioactivity level. If the landfill operator confirms that the radioactivity level 

exceeds the threshold, Eureka pays a surcharge in addition to the disposal cost in Table 3-4.

Eureka indicated that of the types of solid waste they generate, waste from high TSS influent 

wastewaters is most likely to exceed the 10 micorems per hour threshold, but the frequency is 

extremely low (i.e., less than 5 times over several years).

3.5 Costs

Eureka reported general prices that they charge to customers based on level of treatment, 

type of service, and incoming wastewater quality. The base price for chemical treatment to 

operators that are able to take a load of treated wastewater is approximately $3.25 per barrel. If 

an operator is dropping a load off for disposal, Eureka charges the operator for the full treatment 

process (approximately $10 per barrel). In general, Eureka surcharges operators for wastewater 

with high concentrations of TSS, TDS, iron, strontium, barium, and gels, and polymers. 

Occasionally, operators who unsuccessfully treated flowback in the field will bring wastewater 

containing polymers, which then requires significantly more chemical to treat. Eureka has also 

received wastewater from gel fracturing during early Marcellus development, which requires 

more chemical to treat and causes operational problems. Eureka explained that they are able to 

treat this type of wastewater but at a higher cost to the operator. However, operators have 

predominantly used slickwater fracturing in the Marcellus. Table 3-3and Table 3-4 provide an 

overview of Eureka’s treatment and operational costs.

Table 3-3. Eureka’s Wastewater Treatment Costs

Wastewater 

Type Service Type of Treatment

Approximate Cost

(Dollars per bbl)

Low TSS

(Flowback and 

Produced 

Water)

Disposal Chemical treatment, filtration, 

evaporation/condensation a 10

Reuse Chemical treatment 3.25 b

Reuse Chemical treatment and 

evaporation/condensation 6.5 — 10 b
3-11

Table 3-3. Eureka’s Wastewater Treatment Costs

Wastewater 

Type Service Type of Treatment

Approximate Cost

(Dollars per bbl)

High TSS

(Top hold, 

drilling fluid)

Reuse Chemical treatment 7—16 

Disposal Chemical treatment, 

evaporation/condensation a 16

a—Distillate from evaporation/condensation is discharged to POTW and concentrated brine hauled to Ohio.

b—Eureka charges a surcharge for any wastewater over 150,000 mg/L TDS due to an increase in chemical 

required. Surcharges may increase the per barrel cost up to $15.50 per barrel.

Table 3-4. Eureka’s Operational Costs

Waste Type Destination Transportation Cost Disposal Fee Total Cost

Solid waste Landfill 16—20 a

(dollars per ton) 

50

(dollars per ton)

66—70 

(dollars per ton)

Concentrated 

brine

Ohio 

underground 

injection

9—13

(dollars per barrel)

2.5—4.5 b

(dollars per barrel)

12.5—15

(dollars per barrel)

Distillate Williamsport 

POTW N/A $0.378(dollars per barrel)

$0.378 c

(dollars per barrel) 

a—Each truck hauls approximately 15 tons.

b—Injection of concentrated brine costs $2.5 to $4.5 per barrel. Injection of flowback wastewater, which is less 

dense and requires more energy input to inject, costs $4.5 to $6.75 per barrel.

c—The Williamsport POTW may surcharge Eureka if BOD concentrations are too high. This price was reported 

as approximately $9 per 1,000 gallons.

N/A—Not Applicable.

NR—Not Reported.
APPENDIX A

LIST OF PARTICIPANTS ON THE EUREKA SITE VISIT
Table A-1. List of Attendees

First Name Organization Phone Number Email

Lisa Biddle U.S. EPA, SGE Engineer (202) 566-0350 Biddle.Lisa@epa.gov

Tom Born U.S. EPA, SGE Environmental

Scientist (202) 566-1001 Born.Tom@epa.gov

Brian D’Amico U.S. EPA, SGE Engineer (202) 566-1069 Damico.Brian@epa.gov

Erik Helm U.S. EPA, SGE Economist (202) 566-1049 Helm.Erik@epa.gov

Pooja Parikh U.S. EPA, SGE Attorney (202) 564-0839 Parikh.Pooja@epa.gov

Jerel Bogden Eureka (716) 560-5413 j.bogden@erueka-resources.com

Dan Ertel Eureka (570) 971 - 9978 d.ertel@erueka-resources.com

John Staton Eureka, Vice President of 

Operations (570) 295-1438 j.staton@erueka-resources.com

Casey MacQueen ERG, Chemical Engineer (703) 633-1686 Casey.Macqueen@erg.com

Brent Ruminski ERG, Energy Engineer (703) 633-1701 Brent.Ruminski@erg.com