E

C

/R Incorporated Providing Environmental Technical Support Since 1989

501 Eastowne Drive, Suite 250  Chapel Hill, North Carolina 27514

Telephone: (919)484-0222  Fax: (919) 484-0122

 

MEMORANDUM

DATE: April 17, 2012

SUBJECT: Impacts of Final MACT Standards for Glycol Dehydration Units – Oil and 

Natural Gas Production and Natural Gas Transmission and Storage Source 

Categories

FROM: Heather P. Brown, P.E.

TO: Greg Nizich, EPA/OAQPS/SPPD/FIG

Bruce Moore, EPA/OAQPS/SPPD/FIG

On August 23, 2011, the U.S. Environmental Protection Agency (EPA) proposed amendments to 

two national emissions standards for hazardous air pollutants (NESHAP) for existing and new 

major sources in the Oil and Natural Gas Production (40 CFR part 63, subpart HH) and the 

Natural Gas Transmission and Storage (40 CFR part 63, subpart HHH) source categories. The 

proposed amendments included standards for previously unregulated small glycol dehydration 

units under the authority of sections 112(d)(2) and (3) of the Clean Air Act (CAA). The public 

comment period closed on November 30, 2011, and EPA received several comments regarding 

the impacts of the proposed amendments to the glycol dehydration unit standards.

This memorandum presents the methodology and results of the maximum achievable control 

technology (MACT) floor determinations for HAP emissions from small glycol dehydration 

units in the oil and natural gas production and natural gas transmission and storage source 

categories. 

We determined the MACT floors using data obtained during the development of the original 

1999 MACT standards. We ranked emissions for each of the sources, calculated MACT floor 

averages, and conducted emissions data variability analysis to estimate these best performing 

sources’ emissions performance over time. We determined the MACT floors based on the results 

of these analyses. We also conducted the beyond the floor analyses required by section 

112(d)(2), to evaluate possible standards that would be more stringent than the MACT floor. 

This memorandum also documents impacts associated with the MACT floor for both source 

categories.

DEVELOPMENT OF THE MACT FLOORS FOR SMALL GLYCOL DEHYDRATION 

UNITS FOR THE FINAL NESHAP

The MACT standards for existing sources must be at least as stringent as the average emissions 

limitation achieved by sources in the MACT dataset, that is, the best performing 12 percent of
2

existing sources or the best performing 5 sources for source categories with less than 30 sources, 

i.e., the MACT floor. For new sources, MACT standards must be at least as stringent as the 

control level achieved in practice by the best controlled similar source. The MACT floor for each 

of the HAP are calculated based on the performance of the lowest emitting sources in each of the 

MACT datasets for the oil and natural gas production and natural gas transmission and storage 

source categories.

EPA must exercise its judgment, based on an evaluation of the relevant factors and available 

data, to determine the level of emissions control that has been achieved by the average of the 

best-performing units under variable conditions. The Court has recognized that EPA may 

consider variability in estimating the degree of emissions reduction achieved by best-performing 

sources and in setting MACT floors (see Mossville Envt’l Action Now v. EPA, 370 F.3d 1232, 

1241-42 D.C. Cir 2004), holding that EPA may consider emissions variability in estimating 

performance achieved by best-performing sources and may set the floor at a level that bestperforming sources can expect to meet “every day and under all operating conditions.”

Variability can be accounted for using different statistical methods. For example, recent rules 

have used the upper limit (UL) or the upper prediction limit (UPL) to evaluate variability as part 

of the process for determining the MACT floor emissions limits (e.g., NESHAP for Portland 

Cement Manufacturing). A UL is based on the distribution of the available emissions 

observations (e.g., test runs), and does not embody the predictive aspect that a UPL does. A 

prediction interval (e.g., a UPL) for a future observation is an interval that will, with a specified 

degree of confidence, contain the next (or some other prespecified) randomly selected 

observation from a population. In other words, the prediction interval estimates what future 

values will be, based on present or past measurements. Given this definition, the UPL represents 

the value that the mean of three future test run observations (three-run average) can be expected 

to fall below, based on the results of the independent sample of size (n) from the same 

population. Therefore, should a future test condition be selected randomly from any of these 

sources (i.e., average of three runs), one can be 99 percent confident that the reported level will 

fall below a MACT floor emissions limit calculated using a UPL, assuming representativeness of 

the underlying data set. For these reasons, we used the UPL to account for variability in our 

MACT floor calculations.1

MACT DETERMINATION FOR SOURCE CATEGORIES

The following sections outline the steps taken in determining the MACT floors for the oil and 

natural gas production and natural gas transmissions and storage source categories. We 

calculated emissions rate averages and ranked the top sources, performed statistical analyses to 

account for variability in emissions data and calculated the 99% UPL for each source category.

 

1 Because a source must demonstrate compliance with the MACT floor using the average of a three-run test, the 

appropriate test condition to use to assess variability is three. If a source had to demonstrate compliance by showing 

that each individual test run was below the MACT floor emissions limit, it would be appropriate to use a future test 

condition of one.
3

Ranking the Best Performing Sources

The emissions data used to calculate the MACT floors were obtained using the ICR survey sent 

to oil and natural gas production facilities and natural gas transmission and storage facilities 

during the development of the original 1999 MACT standard. The data used in our MACT floor 

calculation was presented in a separate memorandum issued at proposal2and is presented in 

Appendix A.

We normalized the emissions data in the MACT floor dataset to more accurately identify the best 

performing sources by creating an emission factor in terms of pounds of benzene, toluene, 

ethyelbenzene, and xylene (BTEX) per standard cubic feet of natural gas throughput per parts 

per million by volume (ppmv) inlet BTEX concentration. This emission factor reflects the 

source’s emission level, but also takes into account its natural gas throughput and inlet natural 

gas BTEX concentration. These emission factors, generated for each facility in the MACT floor 

dataset, are presented in Tables 1 and 2 for the oil and natural gas production and the natural gas 

transmission and storage source categories, respectively. 

As shown in Table 1, we ranked the small glycol dehydration units in the oil and natural gas 

production source category for which data were available, and identified the lowest emitting 12 

percent of the sources, which were 11 dehydration units. For the natural gas transmission and 

storage source category, we ranked data for the 15 units for which data were available, and 

identified the lowest emitting 5 dehydration units. This ranking is shown in Table 2. We then 

calculated the MACT floor emissions limits for each source category.

Incorporating Data Variability

Data variability was incorporated after ranking the emissions points. Each emission rate factor 

from the top sources was used in the variability analysis. As discussed previously, the UPL was 

used for the oil and natural gas production and natural gas transmission and storage MACT floor 

variability analyses. 

The first step included a determination of whether the emissions data from the best performing 

sources were normally or log-normally distributed. If the data were normally distributed (e.g., 

similar to a typical bell curve), further variability analyses were conducted on the data set. If the 

data were not normally distributed (for example if the data were asymmetric or skewed to the 

right or left), the type of distribution (e.g., log-normal) was determined and a data transformation 

(e.g., taking the natural log of the data) was performed to normalize the data prior to conducting 

the variability analysis. Two statistical measures, skewness and kurtosis, were examined to 

determine if the data were normally or log-normally distributed.

The skewness statistic (S) characterizes the degree of asymmetry of a given data distribution. 

Normally distributed data have a skewness of zero. The value for S is determined using the Excel 

function “SKEW.” A non-zero S value indicates that the data are asymmetrically distributed. A 

positive S value means that the data distribution has a right tail extending toward positive values. 

 

2 Memorandum from Brown, Heather, EC/R Incorporated, to Moore, B. and Nizich, G., EPA/OAQPS/SPPD/FIG. 

July 28, 2011. Oil and Natural Gas Production MACT and Natural Gas Transmission and Storage MACT – Glycol 

Dehydrators: Impacts of MACT Review Options. Docket Number EPA-HQ-OAR-2010-0505-0047.
4

Table 1. MACT floor for Oil and Natural Gas Production Source Category

Facility 

ID No.

Legacy Docket A-94-04, 

Docket ID No.

Number of 

Unitsa

BTEX Emission Rate Factor

(lb/MMscf-ppmv)

A II-D-10, pg 55 1 2.91E-04

B II-D-09, pg 182 1 4.37E-03

C II-D-19, pg 73 5 4.78E-03

D II-D-19, pg 21 1 6.71E-03

E II-D-10, pg 115 1 9.37E-03

F II-D-19, pg 41 1 1.54E-02

G(1) II-D-19, pg 39 1 1.54E-02

G(2,3,4) II-D-19, pg 39 3 1.54E-02

H II-D-19, pg 79 3 2.77E-02

I II-D-24, pg 42 1 3.93E-02

J II-D-19, pg 27 1 4.18E-02

K II-D-19, pg 43 1 4.32E-02

L II-D-13, pg 40 2 4.33E-02

M II-D-23, pg 41 1 4.34E-02

N II-D-11, pg 53 1 5.49E-02

O II-D-08, pg 19 2 5.71E-02

P II-D-19, pg 53 1 6.41E-02

Q II-D-02, pg 4 1 6.61E-02

R II-D-12, pg 36 6 7.31E-02

S II-D-23, pg 35 1 7.71E-02

T II-D-19, pg 65 3 8.24E-02

U II-D-03, pg 6 30 8.32E-02

V II-D-19, pg 51 2 9.74E-02

W II-D-19, pg 63 3 9.92E-02

X II-D-03, pg 7 1 1.03E-01

Y II-D-10, pg 23 1 1.12E-01

Z II-D-13, pg 42 2 1.16E-01

AA II-D-19, pg 75 3 1.18E-01

BB II-D-19, pg 49 2 1.21E-01

CC II-D-11, pg 27 2 1.31E-01

DD II-D-19, pg 93 1 1.36E-01

EE II-D-23, pg 29 1 1.58E-01

FF II-D-15, pg 57 1 1.86E-01

GG II-D-19, pg 91 3 2.00E-01

HH II-D-13, pg 18 1 2.23E-01

Total 91 6.86E-03 (Avg of top 12 percent)

12 percent of total 11

a Data were submitted by each company for a “representative” glycol dehydration unit. If the number of units that 

were represented by the data submitted was not provided, it was assumed that only one glycol dehydration unit was 

present. For facility G, only one of the dehydration units for which data were submitted was included in the MACT 

floor calculation.
5

Table 2. MACT floor for Natural Gas Transmission and Storage Source Category

Facility 

ID No. a

Legacy Docket A-94-04, 

Docket ID No.

Number of 

Unitsb

BTEX Emission Rate Factor

(lb/MMscf-ppmv)

B IV-G-30, pg 8 1 3.40E-03

C IV-G-30, pg 12 1 3.40E-03

A IV-G-30, pg 10 1 3.40E-03

D IV-G-27, pg 8 1 6.77E-03

E IV-G-27, pg 10 1 1.10E-02

F IV-G-31, pg 19 1 2.64E-02

G IV-G-26, No. 1 1 4.03E-02

I IV-G-24, pg 9 1 8.75E-02

J IV-G-26, No. 2 1 5.49E-02

K IV-G-26, No. 3 1 8.73E-02

L IV-G-26, No. 4 1 9.71E-02

M IV-G-26, No. 5 1 9.81E-02

N IV-G-26, No. 6 1 1.04E-01

O IV-G-26, No. 7 1 1.09E-01

P IV-G-31, pg 27 1 2.36E-01

Total 15 5.59E-03 (Avg of top 5 facilities)

12 percent of total (5 if less 

than 30 units)

5

a

Emission rate factors for facilities A, B and C were normalized to 8,760 hours of operation.

b Data were submitted by each company for a “representative” glycol dehydration unit. If the number of units that 

were represented by the data submitted was not provided, it was assumed that only one glycol dehydration unit was 

present. For facility G, only one of the dehydration units for which data were submitted was included in the MACT 

floor calculation.
6

A negative S value means that the data distribution has a left tail extending toward negative 

values. Further assessment of data normality can be made using the standard error of the 

skewness statistic (SES) shown in Equation 1:

 √

 

 

(Equation 1)

Where:

N = the sample size.

According to the small sample skewness hypothesis test, if S is greater than two times the SES, 

the data distribution can be considered non-normal.

The kurtosis statistic (K) characterizes the degree of peakedness or flatness of a given data 

distribution in comparison to a normal distribution and is determined using the Excel function 

“KURT.” Normally distributed data have a kurtosis of zero. A K value that is greater than zero 

indicates a relatively peaked distribution while a K value less than zero indicates a relatively flat 

distribution. The normality of the data can be further evaluated using the standard error of the 

kurtosis statistic (SEK) shown in Equation 2:

 √

 

 

(Equation 2)

Where:

N = the sample size.

According to the small sample kurtosis hypothesis test, if K is greater than two times the SEK, 

the data distribution is typically considered to be non-normal.

The skewness and kurtosis hypothesis tests were applied to both the reported test values and 

(where necessary) the lognormal values of the reported test values. If the S and K statistics of the 

reported data set were both less than twice the SES and SEK, respectively, the data set was 

classified as normally distributed. If neither of the S and K statistics or only one of these 

statistics was less than twice the SES or SEK, respectively, skewness and kurtosis hypothesis 

tests were conducted for the natural log-transformed data. The distribution most similar to a 

normal distribution was selected as the basis for calculating the UPL. If both the reported values 

and the natural-log transformed reported values had S and K statistics that were greater than 

twice the SES or SEK, respectively, the normally distributed data set was selected as the basis of 

the floor to be protective of the environment. If the results of the skewness and kurtosis 

hypothesis tests were mixed for the reported values and the natural log-transformed reported 

values, the normal distribution was chosen to be protective of the environment.

After determining the distribution of each dataset, a student’s t-test statistic was determined to 

calculate the UPL value. The t-statistic test, which can be found in standard statistical reference 

tables or by using the Excel function “TINV,” requires the degrees of freedom and the desired 

confidence interval. The degrees of freedom was calculated as one less than the number of test 

runs for the two facilities and the confidence interval used was 99 percent.
7

Following the determination of the student’s t-test statistic, the 99 percent UPL values for each 

pollutant were calculated using the test run data for both facilities. Because compliance with the 

MACT floor emissions limit is based on the average of a 3-run test, the UPL was calculated 

using the following equation: 

 ̅ ( ) √ 

 (

 

 

 

 

 

) (Equation 3)

Where:

n = the number of test runs (i.e., sample size),

m = the number of test runs in the compliance average,

s = standard deviation of the emissions test data,

 ̅ = mean, i.e., average of the emissions test data, and

t (0.99, n – 1) = t-statistic for 99% significance and a sample size of n-1.

Equation 3 was applied to the normally distributed data sets. However, for the transformed data, 

the average and the standard deviation of the test runs were replaced with the average and the 

standard deviation of the transformed data. The exponential function of Equation 3 was 

calculated to obtain the 99 percent UPL value.

The 99 percent UPL represents the value that one can expect the mean of future 3-run 

performance tests from the best-performing facilities to fall below with 99 percent confidence, 

based upon the results of the independent sample of observations from the same best performing 

sources. Imprecision due to non-detect values was investigated after determining the 99 percent 

UPL values.

MACT Floor and Variability Analysis Results

Tables 3 and 4 present the results of the MACT floor and variability analyses for the oil and 

natural gas production source category. Tables 5 and 6 present the results of this analysis for the 

natural gas transmission and storage source category.

Table 3 presents the oil and natural gas production source category data used in the variability 

analysis, both the reported values and the lognormal of the reported values. Table 4 presents the 

results of the variability analysis for oil and natural gas production sources. As shown in Table 

4, the results of the skewness and kurtosis hypothesis tests were applied to the reported values. 

The S and K statistics of the reported data set were both less than greater than twice the SES and 

SEK, respectively, and as a result the data set was classified as not normally distributed. 

Therefore, S and K statistics were applied to the natural log-transformed data (presented in Table 

3). As shown in Table 4, the results of the skewness and kurtosis hypothesis tests were mixed for 

the natural log-transformed reported values and as a result, the student’s T-test statistic was 

conducted for the reported data using Equation 3. Based on this analysis, the MACT floor was 

calculated to be 2.05x10-2lb BTEX/MMscf-ppmv for the oil and natural gas production source 

category.

Table 5 presents the data used in the variability analysis for the natural gas transmission and 

storage source category and the results of this analysis are shown in Table 6. As shown in Table 

6, the results of the skewness and jurtosis hypothesis tests were applied to the reported values. 
8

Table 3. MACT Floor Data used in Variability Analysis - Oil and Natural Gas Production 

Facility ID No.

Legacy Docket A94-04

Docket ID No.

BTEX Emission

Rate Factor

(lb BTEX/MMscf-ppmv)

Ln(BTEX Emission

Rate Factor)

A II-D-10, pg 55 2.91E-04 -8.142

B II-D-09, pg 182 4.37E-03 -5.434

C II-D-19, pg 73 4.78E-03 -5.343

C II-D-19, pg 73 4.78E-03 -5.343

C II-D-19, pg 73 4.78E-03 -5.343

C II-D-19, pg 73 4.78E-03 -5.343

C II-D-19, pg 73 4.78E-03 -5.343

D II-D-19, pg 21 6.71E-03 -5.004

E II-D-10, pg 115 9.37E-03 -4.671

F II-D-19, pg 41 1.54E-02 -4.174

G II-D-19, pg 39 1.54E-02 -4.173

Table 4. MACT Floor and Variability Analysis Results - Oil and Natural Gas Production

Total Facility Count 91 # Facilities

Top 12 Percent 11 # Facilities

Avg Top 12 percent 0.00686 lb BTEX/MMscf-ppmv

Avg Top 12 Natural Log Transformed -5.30112 lb BTEX/MMscf-ppmv

Min Run in Top 5 0.00029 lb BTEX/MMscf-ppmv

Max Run in Top 5 0.01541 lb BTEX/MMscf-ppmv

Top 12 percent number of data points 11 # of runs

Sample Size (n) 11 # of runs

Skewness (S) 1.07

Std Error of Skewness (SES) 0.74

Reported Skewness Test (reported values) S/SES 1.44

Values non-normal S/SES>=2

Kurtosis (K) 0.50

Std Error of Kurtosis (SEK) 1.48

Kurtosis Test (reported values)

K/SEK 0.34

non-normal K/SEK>2

Skewness (S) -2.06

Std Error of Skewness (SES) 0.74

Skewness Test (reported values) S/SES -2.79

Natural Log normal S/SES<2

Transformed Kurtosis (K) 5.98

Values Std Error of Kurtosis (SEK) 1.48

Kurtosis Test (reported values)

K/SEK 4.05

non-normal K/SEK>=2

99% UPL (reported values) 2.05E-02 lb BTEX/MMscf-ppmv
9

Table 5. MACT Floor Data used in Variability Analysis - Natural Gas Transmission and 

Storage

Facility ID No.

Legacy Docket A94-04

Docket ID No.

BTEX Emission

Rate Factor

(lb BTEX/MMscf-ppmv)

B IV-G-30, pg 8 3.40E-03

C IV-G-30, pg 12 3.40E-03

A IV-G-30, pg 10 3.40E-03

D IV-G-27, pg 8 6.77E-03

E IV-G-27, pg 10 1.10E-02

Table 6. MACT Floor and Variability Analysis Results - Natural Gas Transmission and 

Storage 

Total Facility Count 16 # Facilities

Top 12 Percent 5 # Facilities

Ave Top 12 percent 0.00559 lb BTEX/MMscfppmv

Min Run in Top 5 0.00340 lb BTEX/MMscfppmv

Max Run in Top 5 0.01098 lb BTEX/MMscfppmv

Top 12 percent number of data points 5 # of runs

Sample Size (n) 5 # of runs

Skewness (S) 1.41

Std Error of Skewness (SES) 1.10

Reported Skewness Test (reported values) S/SES 1.28

Values Normal S/SES<2

Kurtosis (K) 1.10

Std Error of Kurtosis (SEK) 2.19

Kurtosis Test (reported values)

K/SEK 0.50

Normal K/SEK<2

99% UPL (normal distribution) 0.019 lb BTEX/MMscfppmv
10

The S and K statistics of the reported data set were both greater than twice the SES and SEK, 

respectively, and as a result, the data set was classified as normally distributed. The student’s Ttest statistic was then conducted for the reported data using Equation 3. Based on this analysis, 

the MACT floor was calculated to be 1.93x10-2lb BTEX/MMscf-ppmv for the natural gas 

transmission and storage source category.

For new sources, the MACT floor is the best controlled single source. Since the emissions data 

in the MACT dataset represents one data point for each source, a statistical variability analysis 

cannot be applied. As such, the new source MACT is 2.91x10-4lb BTEX/MMscf-ppmv for the 

oil and natural gas production source category and 3.40x10-3lb BTEX/MMscf-ppmv for the 

natural gas transmission and storage source category.

AFFECTED SOURCES

To identify the existing small glycol dehydration units that would be subject to the MACT 

standard, we used the 2005 National Emissions Inventory (NEI) dataset.3 Within this dataset, we 

identified 368 facilities in the oil and natural gas production sector with one or more glycol 

dehydration units, with a total of 642 glycol dehydration units. The small glycol dehydration unit 

MACT standard only applies to each glycol dehydration unit in the production source category 

that has a natural gas throughput less than 3 MMscf/day or benzene emissions less than 1 tpy. 

We therefore considered the following glycol dehydration units in the production source 

category to be small glycol dehydration units:

 Glycol dehydration units with uncontrolled benzene emissions less than 1 tpy;

 Glycol dehydration units with uncontrolled benzene emissions greater than 1 tpy; and

 Glycol dehydration units with controlled benzene emissions less than 0.05 tpy.

Glycol dehydration units with uncontrolled benzene emissions less than 1 tpy are by definition 

considered to be small dehydrators. Also considered to be small glycol dehydrators by definition 

would be units with natural gas throughput less than 3 MMscf/day. However, the NEI dataset 

does not have sufficient throughput data to identify these units. Therefore, assuming that all 

reported units were either complying with the existing subpart HH or exempt, any glycol 

dehydration unit that had uncontrolled benzene emissions greater than 1 tpy must meet the 

3 MMscf/day cutoff. Finally, it was also necessary to identify any units that were currently being 

controlled, even though they met the definition of a small glycol dehydration unit and were not 

subject to the existing subpart HH. Therefore, glycol dehydration units with controlled benzene 

emissions less than 0.05 were assumed to achieve emission reductions of 95 percent, making 

their uncontrolled emissions less than 1 tpy.

Using these assumptions, we identified 495 small glycol dehydration units. The next step was to 

identify which of these small glycol dehydration units would be required to reduce their 

emissions to meet the MACT floor. However, the NEI dataset does not have BTEX inlet 

concentrations, and as mentioned previously, it does not have sufficient throughput data. 

 

3 Memorandum from Wilson, D. et al, ERG, to A. Pope, U.S. Environmental Protection Agency. Documentation for 

NEI Updates for Oil and Natural Gas Production and Natural Gas Transmission and Storage. March 15, 2011. 

Docket Number EPA-HQ-OAR-2010-0505-0022.
11

Therefore, a direct comparison to the MACT floor in the form of an emission factor was not 

possible. Instead, an equivalent value for the MACT floor in terms of tons per year was 

established. Appendix A presents the BTEX emissions associated with the MACT floor of 

2.05x10-2 lb BTEX/MMscf-ppmv. As shown in Appendix A, we calculated an equivalent value 

0.955 tpy BTEX. Any glycol dehydration unit identified as a small glycol dehydration unit with 

controlled or uncontrolled BTEX emissions greater than 0.955 tpy would be required to reduce 

their emissions to a level below 0.955 tpy BTEX. Appendix B presents the facilities and glycol 

dehydration units that would be affected by the MACT standard for small glycol dehydration 

units.

As shown in Appendix B, 74 glycol dehydration units would be required to reduce their 

emissions to meet the MACT floor of 2.05x10-2 lb BTEX/MMscf-ppmv (or 0.955 tpy). Of 

these 74 units, 67 glycol dehydration units required 95 percent emission reduction or less to meet 

the floor (assumed to be met using a condenser). The remaining units required more than 

95 percent control to meet the MACT floor and these units were assumed to require the 

installation of a vapor recovery unit (VRU) in combination with a condenser (assumed combined 

99.75 percent reduction). It should be noted that the specific control technologies are not 

required, but were assumed in order to determine the cost impacts, which will be discussed later.

In the NEI dataset for the transmission and storage source category, a total of 146 glycol 

dehydration units were identified at 63 facilities. The same procedure to identify the small glycol 

dehydration units in the production source category was used for the transmission and storage 

source category. Small glycol dehydration units in the transmission and storage source category 

are defined as units with benzene emissions less than 1 tpy or natural gas throughputs less than 

10 MMscf/day. A total of 110 glycol dehydration units were identified with: (1) uncontrolled 

benzene emissions less than 1 tpy; (2) uncontrolled benzene emission greater than 1 tpy, or 

(3) controlled benzene emissions less than 0.05 tpy. Attachment 2 presents these small glycol 

dehydration units identified for the transmission and storage source category. As shown in 

Table 8, the MACT floor of 1.93x10-2lb BTEX/MMscf-ppmv for the transmission and storage 

source category is equivalent to 11.84 tpy of BTEX. Of the 110 small glycol dehydration units 

identified, 7 would be required to install controls to achieve the MACT floor (see Appendix C); 

all of which were assumed, for the purposes of estimating cost impacts, to install condensers 

(assumed to achieve an emission reduction of 95 percent).

COST IMPACTS

The cost impacts due to the application of control devices to meet the small glycol dehydration 

unit MACT standards include the cost of the control equipment that must be purchased, along 

with the cost of the installation of that control equipment. There are also costs for the operation 

and maintenance of the equipment. This section presents the estimated costs associated with 

compliance with the MACT standards. To meet the MACT floor, we anticipated that sources 

would use a wide variety of emissions, including, but not limited to, routing emissions to a 

condenser or to a vapor recovery unit.4These control technologies are not required by the 

 

4 Although operational issues such as VRU capacity may exist, the installation of a VRU was assumed for the 

purposes of determining potential impacts as a conservative assumption. This type of control technique is not 

required by the standards.
12

standards, but were assumed for the purposes of evaluating the cost impacts related the small 

glycol dehydration unit MACT standards.

As previously discussed, the emission reduction required to meet the MACT floor for both the 

oil and natural gas production and natural gas transmission and storage source categories was 

determined by comparing the individual dehydration unit’s BTEX emissions to the MACT floor 

(in terms of tpy of BTEX) associated with the source category. If the dehydration unit emissions 

were greater than the MACT floor, control was required regardless of whether the unit was 

already equipped with a control device. If the emission reduction required to achieve a level 

emissions below the MACT floor was less than the assumed level of control for a condenser (95

percent), we assumed, for cost purposes, that the facility would install a condenser. Likewise if 

the required reduction was greater than 95% but less than 99.75%, we assumed that the facility 

would install a VRU and a condenser (assumed to achieve a combined emission reduction of 

99.75%). If the facility was already controlled, it was assumed that a vapor recovery unit 

(assumed to achieve 95% control) would be installed. 

We originally developed cost estimates for condensers for the 1998 proposed subpart HH and 

HHH and are documented in the Background Information Document (BID).5The original cost 

estimates were based on 1993 cost data. Therefore, we revised these estimates to reflect 2008 

prices using the Chemical Engineering6cost index for equipment costs and information from the 

Bureau of Labor Statistics for labor rates.

7

For units identified for which it was assumed that condensers would be installed, we assumed 

that 10 percent of the units would already be equipped with a flash tank and the remaining 

90 percent would be required to install a flash tank in addition to the condenser. Table 7 presents 

the updated capital costs for installing a condenser on a dehydration unit that must install a flash 

tank to comply with the MACT standards. Table 8 presents a summary of the estimated capital 

costs for installing a condenser on glycol dehydration units that are already equipped with a flash 

tank. Table 9 presents the estimated annual cost for condensers.

The capital costs for glycol dehydration units for which vapor recovery units would be installed 

(either alone or in combination with a condenser) are presented in Table 10. We based these 

costs on a study performed on the installation of an environmental VRU.8Emissions from the 

glycol dehydration unit would be piped to a condensate tank equipped with a VRU. No 

additional emission reduction benefits from the control of the condensate tanks were estimated in 

this analysis. Table 11 presents the annual costs for VRUs.

 

5 U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards. Research Triangle Park, 

NC. National Emission Standards for Hazardous Air Pollutants for Source Categories: Oil and Natural Gas 

Production and Natural Gas Transmission and Storage. Background Information Document for Proposed Standards. 

EPA-453/R-94-079a.

6 Chemical Engineering. http://www.che.com. August 2004. Economic Indicators.

7

“Employer Costs for Employee Compensation Historical Listing. March 2004 – September 2010. Bureau of 

Labor Statistics. Washington, DC. (ftp://ftp.bls.gov/pub/special.requests/ocwc/ect/ececqrtn.pdf) Table 9 – Private 

industry workers, by major occupational group: employer costs per hours worked for employee compensation and 

costs as a percentage of total compensation; 2004 – 2010. Management hours (Management, professional, and 

related occupations); Technical labor rates (Natural resources, construction, and maintenance occupations).

8 Environmental Technology Verification Report. COMM Engineering, USA. September 2002.
13

Table 7. Total Capital Investment for Small Glycol Dehydration Units that Install a 

Condenser plus Flash Tank (Dehy-A)

Equipment Description Size Factor Reference

Jul-93 

Cost

2008

Costa

Condenser Condenser, 

piping to 

control device

All 9 $6,800b$9,921

Storage tank 

to collect 

condensates

Fixed-roof 

tank

50 gal 2.72 (Vtank) + 1,960 10 $2,210 $3,224

Flash tank Low pressure 

separator

125 psig 11 $1,750 $2,553

Purchased equipment cost (PEC) c$10,760 $15,698

Enhanced monitoring equipment (EM) 0.10(PEC) $1,076 $1,570

Total capital investment for a new unit 

(TCIN) c

PEC + EM $11,840 $17,270

Total capital investment for an existing 

unit (TCIE)d

1.15(TCIN) $13,620 $19,860

Minor discrepancies may be due to rounding.

a

Costs escalated from July 1993 dollars to 2008 dollars using the ratio of Chemical Engineering cost indices 

(Reference 6). July 1993 Cost Index = 394.4; 2008 Cost Index = 575.4.

b Direct and indirect costs are included in the condenser cost.

c

Procedures followed from OAQPS Control Cost Manual for calculating PEC and TCI (Reference 10).

dTotal capital investment for an existing unit accounts for a retrofit factor of 1.15.

 

9

See Reference 5.

10 OAQPS Control Cost Manual: Fourth Edition (EPA 450/3-90-006, January 1990). U.S. Environmental Protection 

Agency. Research Triangle Park, NC.

11 See Reference 5.
14

Table 8. Total Capital Investment for Small Glycol Dehydration Units that Install a 

Condenser (Dehy-B)

Equipment Description Size Factor Reference

Jul-93 

Cost

2008

Costa

Condenser Condenser, 

piping to 

control device

All 12 $6,800b$9,921

Storage tank 

to collect 

condensates

Fixed-roof 

tank

50 gal 2.72 (Vtank) + 1,960 13 $2,210 $3,224

Purchased equipment cost (PEC) c$9,010 $13,145

Enhanced monitoring equipment (EM) 0.10(PEC) $901 $1,314

Total capital investment for a new unit 

(TCIN) c

PEC + EM $9,910 $14,460

Total capital investment for an existing 

unit (TCIE)d

1.15(TCIN) $11,400 $16,630

Minor discrepancies may be due to rounding.

a

Costs escalated from July 1993 dollars to 2008 dollars using the ratio of Chemical Engineering cost indices 

(Reference 6). July 1993 Cost Index = 394.4; 2008 Cost Index = 575.4.

b

Direct and indirect costs are included in the condenser cost.

c Procedures followed from OAQPS Control Cost Manual for calculating PEC and TCI (Reference 10).

d

Total capital investment for an existing unit accounts for a retrofit factor of 1.15.

 

12 See Reference 5.

13 See Reference 10.
15

Table 9. Total Annual Costs for Small Glycol Dehydration Units that Install Condensers 

(Dehy-A and Dehy-B)a

Cost Component Factor Dehy-A Dehy-B

Direct Annual Costs (DAC)b

Operating labor 130 hours/yr x $technical labor ratec$3,960 $3,960 

Supervising labor 0.15 x Operating labor x management labor rated937 594 

Operating 

materials

None required 0 0 

Maintenance

 Labor 130 hours/yr x $technical labor ratec3,960 3,960 

 Material 0.50 x Maintenance labord1,980 1,980 

Utilities None required

Indirect Annual Costs (IAC)b

Overhead 0.60 x Total labor + Maintenance $5,314 $5,109 

Administrative 0.02 x TCIEe397 333 

Property tax 0.01 x TCIE e199 166 

Insurance 0.01 x TCIE e199 166 

Capital recoveryf0.1098 x TCIE e2,181 1,826 

Total Net Annual Cost (DAC + IAC) $19,100 $18,100 

Minor discrepancies may be due to rounding.

a

Existing Unit Dehy-B assumed to be equipped with a flash tank (Table 4). Existing Unit Dehy-A does not and a 

flash tank has been added to the capital cost (see Table 3).

b

Procedures followed from OAQPS Control Cost Manual for calculating DAC and IAC (Reference 10).

c

Technical Labor Rate = $30.46/hr (Reference 7)

d Management Labor Rate = $48.04/hr (Reference 7)

e

TCIE from Table 3 for Dehy-A and Table 4 for Dehy-B

f

Capital recovery is based on equipment life of 15 years and an interest rate of 7%.
16

Table 10. Total Capital Investment for Small Glycol Dehydration Units that Install a 

Vapor Recovery Unit

Equipment Description Size Factor Reference 2002 Cost

2008

Costa

VRU Vapor 

Recovery Unit

All 14 $69,510 $101,102

Includes transportation and delivery

Purchased equipment cost (PEC) b$69,510 $101,102

Labor,and Materials for Installation Costs 

(L&M)

15 $38,448 $55,923

Total capital investment for a new unit 

(TCIN)b

PEC + L&M $107,960 $157,020

Total capital investment for an existing 

unit (TCIE) c

1.15(TCIN) $124,150 $180,570

Minor discrepancies may be due to rounding.

a

Costs escalated from 2002 dollars to 2008 dollars using the ratio of Chemical Engineering cost indices 

(Reference 6). 2002 Cost Index = 395.6; 2008 Cost Index = 575.4.

b

Procedures followed from OAQPS Control Cost Manual for calculating PEC and TCI (Reference 10).

c Total capital investment for an existing unit accounts for a retrofit factor of 1.15.

 

14 See Reference 8.

15 See Reference 8.
17

Table 11. Total Annual Costs for Small Glycol Dehydration Units that Install a Vapor 

Recovery Unit

Cost Component Factor Dehy-A

Direct Annual Costs (DAC) a

Operating labor 130 hours/yr x $technical labor rateb$3,960 

Supervising labor 0.15 x Operating labor x management labor ratec937 

Operating 

materials

None required 0 

Maintenance

 Labor 130 hours/yr x $technical labor rateError! 

Bookmark not defined.b

3,960 

 Material 0.50 x Maintenance laborc1,980 

O&M $3,000/yr (2005 dollars) escalated to 2008 

dollars16

3,687 

Indirect Annual Costs (IAC)a

Overhead 0.60 x Total labor + Maintenance $5,314 

Administrative 0.02 x TCIEd3,611

Property tax 0.01 x TCIE d1,806

Insurance 0.01 x TCIE d1,806

Capital recoverye0.1098 x TCIE d19,827

Total Net Annual Cost (DAC + IAC) $46,900 

Minor discrepancies may be due to rounding.

a

Procedures followed from OAQPS Control Cost Manual for calculating DAC and IAC (Reference 10).

b Technical Labor Rate = $30.46/hr (Reference 7)

c Management Labor Rate = $48.04/hr (Reference 7)

d TCIE from Table 3 for Dehy-A and Table 4 for Dehy-B

e Capital recovery is based on equipment life of 15 years and an interest rate of 7%.

 

16 Fernandez, R, U.S. Environmental Protection Agency, Natural Gas STAR Program, et al. "Cost Effective 

Methane Emissions Reductions for Small and Midsize Natural Gas Producers" Journal of Petroleum Technology. 

June 2005
18

We estimated the nationwide impacts of the small glycol dehydration units MACT standards by 

multiplying the number of affected units by the costs. Tables 12 and 13 present the nationwide 

impacts for the oil and natural gas production and the transmission and storage source categories, 

respectively. We assigned control technologies to the facilities in Appendices B and C, according 

to the level of control required to meet the MACT floor.

Beyond the Floor Analysis

We also considered beyond-the-floor options for the existing sources, as required by section 

112(d)(2) of the CAA. To achieve further reductions beyond the MACT floor level of control,

sources would have to install an additional add-on control device, most likely a combustion 

device. Assuming the MACT floor control device is a condenser, which generally achieves at 

least a 95-percent HAP reduction, then less than 5 percent of the initial HAP emissions remain.

We estimated costs for a combustor in a separate memorandum for storage vessels.17 We 

estimated that the annual cost for a combustion device would be approximately $19,580/yr. 

Table 14 presents the analysis for installing a combustion device to reduce emissions by an 

additional 95 percent. As shown in Table 14, the incremental cost effectiveness ranged 

from$72,000/ton to $630,000/ton for oil and natural gas production. The incremental cost 

effectiveness ranged from $16,000/ton to $24,000/ton for natural gas transmission and storage.

We do not believe this cost to be reasonable given the level of emission reduction. Therefore, we 

rejected a beyond-the-floor level of control and the final standards for existing small dehydrators 

reflect the MACT floor.

SECONDARY ENVIRONMENTAL IMPACTS

Although the intent of the MACT standards for small glycol dehydration units is to reduce HAP 

emissions, the application of control technologies can lead to other secondary environmental 

impacts. These secondary impacts can have a positive environmental impact, such as the 

reduction of VOC emissions, or a negative impact. Negative impacts may result from air 

pollutants emitted as a result of combustion sources (e.g., flares) or generation of a solid or liquid 

waste stream. The secondary impacts on air pollution, water and solid waste, and energy are 

discussed in this section.

Air Pollution Impacts

The primary method of HAP control from small glycol dehydration units is the installation of a 

condenser and, if not present, a flash tank or the installation of a VRU. The secondary air 

pollution impacts associated with the application of this type of control are the decreased VOC 

emissions resulting from capture and control of HAP emissions. We do not expect adverse 

secondary air impacts from either of these control technologies.

 

17 Memorandum from Brown, H., EC/R Incorporated, to Nizich, G., and Moore, B., EPA/OAQPS/SPPD/FIG. 

Update to Technical Support Document for Proposed Standards of Performance for Crude Oil and Natural Gas 

Production, Transmission, and Distribution – Storage Vessels. April 17, 2012.
19

Table 12. Nationwide Cost Impacts for the Oil and Natural Gas Production Source Category

Control Technologya

Total Capital 

Investment 

Per Existing 

Unit ($)b

Number 

of 

Affected 

Units

Nationwide 

Total 

Capital 

Investment 

($)

Total Annual 

Cost per 

Existing Unit 

($/yr)c

Nationwide Total 

Annual Cost 

($/yr)

Baseline 

HAP 

Emissions 

(tpy)

HAP 

Emission 

Reduction 

(tpy)

HAP Cost 

Effectiveness 

($/ton)

Install Condenser + Flash 

Tank

19,860 60 $1,191,600 $19,100 $1,146,000 344 327 $3,507

Install Condenser 16,630 7 $116,410 $18,100 $126,700 38.2 36 $3,489

VRU + Condenser + Flash 

Tank

200,430 2 $400,860 $66,000 $132,000 117.97 117.68 $1,122

VRU + Condenser 197,200 1 $197,200 $65,000 $65,000 13.11 13.08 $4,971

VRU Only 180,570 4 $722,280 $46,900 $187,600 11.41 10.84 $17,313

Total 74 $2,628,350 $1,657,300 525 505 $3,284

Minor discrepancies may be due to rounding.

a

Assumed that 10 percent of units are equipped with a flash tank (supported by MACT Floor dataset). In order for the condenser to operate properly, a flash tank must be 

installed. Costs reflect the addition of a flash tank where none is present.

b

See Tables 3, 4, and 6.

c

See Tables 5 and 7.
20

Table 13. Nationwide Cost Impacts for the Natural Gas Transmission and Storage Source Category

Control Technologya

Total Capital 

Investment 

Per Existing 

Unit ($)b

Number 

of 

Affected 

Unit

Nationwide 

Total 

Capital 

Investment 

($)

Total 

Annual 

Cost per 

Existing 

Unit ($/yr)c

Nationwide 

Total 

Annual 

Cost ($/yr)

Baseline 

HAP 

Emissions 

(tpy)

HAP 

Emission 

Reduction 

(tpy)

HAP Cost 

Effectiveness 

($/ton)

Install Condenser + Flash Tank $19,860 6 $119,160 $19,100 $114,600 156 148 $775

Install Condenser $16,630 1 $16,630 $18,100 $18,100 17.3 16 $1,102

Total 7 $135,790 $132,700 173 164 $808

Minor discrepancies may be due to rounding.

a

Assumed that 10 percent of units are equipped with a flash tank (supported by MACT Floor dataset). In order for the condenser to operate properly, a flash tank must be 

installed. Costs reflect the addition of a flash tank where none is present.

b

See Tables 3, 4, and 6.

c

See Tables 5 and 7.
21

Table 14. Beyond the Floor Analysis for Oil and Natural Gas Production and Natural Gas Transmission and Storage

Control Technologya

Number of 

Affected 

Unitsa

Nationwide 

Baseline HAP 

Emissions 

(tpy)a

Nationwide 

HAP 

Emission 

Reduction 

Associated 

with MACT 

floor (tpy)a

Nationwide Additional 

Emission Reduction 

Associated with 

Beyond the Floor 

(tpy)b

Annual Cost 

of 

Combustion 

Device 

($/yr)18

Nationwide 

Annual Cost 

of 

Combustion 

Device 

($/yr)c

Incremental 

Cost 

Effectiveness 

($/ton)d

Oil and Natural Gas Production

Install Condenser + Flash 

Tank

60 344 327 16.3 $19,580 1,174,792 71,893

Install Condenser 7 38.2 36 1.82 $19,580 137,059 75,488

VRU + Condenser + Flash 

Tank

2 117.97 117.68 0.280 $19,580 39,160 139,764

VRU + Condenser 1 13.11 13.08 0.0311 $19,580 19,580 628,939

VRU Only 4 11.41 10.84 0.542 $19,580 78,319 144,561

74 525 505 19.0 1,448,910 75,899

Natural Gas Transmission and Storage

Install Condenser + Flash 

Tank

6 156 148 7.4 $19,580 117,479 15,888

Install Condenser 1 17.3 16 0.82 $19,580 19,580 23,832

7 173 164 8.22 137,059 16,683

a

From Tables 12 and 13 above.

b Calculated by assuming that a combustion device would get a 95 percent emission reduction, applied to the emissions remaining after MACT floor level of control is applied.

c

Total annual cost for combustion device times number of impacted units.

d

Incremental cost effectiveness is the difference in annual cost between the MACT floor and the beyond the floor alternative divided by the additional emission reduction achieved 

by the beyond the floor alternative. In this case, the difference in annual cost is equivalent to the annual cost of the new combustion device.

 

18 See Reference 17.
22

Water and Solid Waste Impacts

The water impacts associated the installation of a condenser system for the glycol dehydration 

unit reboiler vent would be minimal. The condensed water collected with the hydrocarbon 

condensate can be directed back into the system for reprocessing with the hydrocarbon 

condensate or, if separated, combined with produced water for disposal by reinjection.5 No 

water impacts would be associated with the operation of a VRU.

There is no solid waste generated from the control of HAP emissions using condensers and/or 

VRUs. Therefore, we do not anticipate any adverse solid waste impacts from the implementation 

of the MACT standards for small glycol dehydration units.

Energy Impacts

Energy impacts are those energy requirements associated with the operation of emission control 

devices. There would be no national energy demand increase expected from the operation of any 

of the control options analyzed under the MACT standards for small glycol dehydration units. It 

is assumed that the types of control technologies that would be implemented to meet the MACT 

standards for small glycol dehydration units would be the types of controls that recover

hydrocarbon products, such as natural gas and condensate, which can be used on-site as fuel or 

reprocessed, within the production process, for sale. Thus, it was assumed that the standards 

would have a positive impact associated with the recovery of non-renewable energy resources.
APPENDIX A

A-1

MACT Floor analysis for Glycol Dehydration Units in the Oil and Natural Gas Production Source Category

Unit 

ID 

No.

Legacy Docket A94-04, Docket ID 

No.

Number 

of Units1

BTEX 

Inlet 

Conc. 

(ppmv)

BTEX Emissions (tpy)2

Throughput 

(MMscf/d)

BTEX Emission 

Factor

(lb/MMscf-ppmv)

Equivalent BTEX 

Emissions 

determined by 

Revised Limit (tpy)3B T E X Total

A II-D-10, pg 55 1 116 0.001 0.002 0.000 0.000 0.004 0.62 2.91E-04 0.268

B II-D-09, pg 182 1 69 0.100 0.400 4.0E-01 2.0E-01 1.100 20.00 4.37E-03 5.162

C II-D-19, pg 73 5 60 0.007 0.021 0.016 0.040 0.084 1.60 4.78E-03 0.359

D II-D-19, pg 21 1 140 0.600 0 0 0 0.600 3.50 6.71E-03 1.833

E II-D-10, pg 115 1 39 0 0.10 0 0 0.10 1.50 9.37E-03 0.219

F II-D-19, pg 41 1 308 0.40 0.30 0 0.20 0.90 1.04 1.54E-02 1.198

G II-D-19, pg 39 4 5 0.02 0 0 0 0.02 1.60 1.54E-02 0.030

H II-D-19, pg 79 3 1560 4.90 2.20 0.200 0.60 7.90 1.00 2.77E-02 5.836

I II-D-24, pg 42 1 40 0.64 0.90 1.461 2.011 5.02 17.50 3.93E-02 2.619

J II-D-19, pg 27 1 823 3.00 0.70 0.400 0.300 4.40 0.70 4.18E-02 2.155

K II-D-19, pg 43 1 1499 4.60 1.70 0.10 0.10 6.50 0.55 4.32E-02 3.084

L II-D-13, pg 40 2 1400 1.70 6.10 0.60 9.30 17.70 1.60 4.33E-02 8.380

M II-D-23, pg 41 1 400 1.20 2.60 0 0 3.80 1.20 4.34E-02 1.796

N II-D-11, pg 53 1 340 5.10 1.20 0.30 0.90 7.50 2.20 5.49E-02 2.798

O II-D-08, pg 19 2 348 0.99 1.47 0.15 2.10 4.71 1.30 5.71E-02 1.692

P II-D-19, pg 53 1 174 0.80 3.90 1.00 4.70 10.40 5.11 6.41E-02 3.325

Q II-D-02, pg 4 1 50 0 3.50 0 0 3.50 5.80 6.61E-02 1.085

R II-D-12, pg 36 6 150 0.10 0.10 0 0 0.2 0.10 7.31E-02 0.056

S II-D-23, pg 35 1 400 1.50 3.00 0 0 4.50 0.80 7.71E-02 1.197

T II-D-19, pg 65 3 216 0.40 1.40 0.10 2.00 3.90 1.20 8.24E-02 0.970

U II-D-03, pg 6 30 316 0.50 2.30 0.20 1.80 4.80 1.00 8.32E-02 1.182

V II-D-19, pg 51 2 329 1.30 4.20 0.60 5.60 11.7 2.00 9.74E-02 2.462

W II-D-19, pg 63 3 102 0.30 0.50 0 0.40 1.20 0.65 9.92E-02 0.248

X II-D-03, pg 7 1 668 0.60 4.20 0.70 8.30 13.80 1.10 1.03E-01 2.749

Y II-D-10, pg 23 1 157 0.20 0.10 0.500 1.60 2.40 0.75 1.12E-01 0.440

Z II-D-13, pg 42 2 2560 0.70 2.20 0.20 2.30 5.40 0.10 1.16E-01 0.958

 

1

Data were submitted by each company for a “representative” glycol dehydration unit. If the number of units that were represented by the data submitted 

was not provided, it was assumed that only one glycol dehydration unit was present.

2

BTEX emissions either provided by each company or calculated using GLYCalc Version 3.0 using the glycol dehydration unit operational data submitted.

3

Calculated using revised MACT limit of 2.05x10-2lb BTEX/MMscf-ppmv (revised using UPL variability) and each facility’s BTEX concentration and throughput.
APPENDIX A

A-2

MACT Floor analysis for Glycol Dehydration Units in the Oil and Natural Gas Production Source Category

Unit 

ID 

No.

Legacy Docket A94-04, Docket ID 

No.

Number 

of Units1

BTEX 

Inlet 

Conc. 

(ppmv)

BTEX Emissions (tpy)2

Throughput 

(MMscf/d)

BTEX Emission 

Factor

(lb/MMscf-ppmv)

Equivalent BTEX 

Emissions 

determined by 

Revised Limit (tpy)3B T E X Total

AA II-D-19, pg 75 3 320 1.3 2.6 0.30 2.7 6.9 1.00 1.18E-01 1.197

BB II-D-19, pg 49 2 198 0.7 2.4 0.20 2.0 5.3 1.21 1.21E-01 0.898

CC II-D-11, pg 27 2 920 10.5 18.0 5.50 25.3 59.3 2.70 1.31E-01 9.292

DD II-D-19, pg 93 1 19 0.2 0.7 0.40 1.7 3.0 6.34 1.36E-01 0.451

EE II-D-23, pg 29 1 500 1.2 1.9 0 1.5 4.6 0.32 1.58E-01 0.599

FF II-D-15, pg 57 1 32 0.2 1.8 0.20 0.3 2.5 2.30 1.86E-01 0.275

GG II-D-19, pg 91 3 39 0.2 1.0 0.10 0.6 1.9 1.34 2.00E-01 0.195

HH II-D-13, pg 18 1 410 0.70 0.10 0.40 0.30 1.50 0.09 2.23E-01 0.138

91 Total Number of Units Avg of top 12%46.86E-03 0.955

11512% of Total

 

4 MACT floor of 0.286 tpy BTEX and 6.86x10-3

lb BTEX/MMscf-ppmv calculated by averaging BTEX emissions and BTEX emission factor, respectively, from the 

top 11 facilities (which represent 12 percent of the total).

5

Shaded cells represent facilities considered in the MACT floor. There are four glycol dehydration units represented by item II-D-19, pg 39 and only one unit is 

included in the floor calculations.
APPENDIX A

A-3

MACT Floor analysis for Glycol Dehydration Units in the Natural Gas Transmission and Storage Source Category

Facility

ID No.6

Docket 

ID

No.

of 

Units

BTEX

Inlet 

Conc. 

(ppmv)

Reported 

hours of 

operation 

(hr/yr)

BTEX Emissions based on 

Reported Hours of Operation 

(tpy)7

BTEX Emissions based on Full Time 

Operation (tpy)7

Throughput 

(MMscf/D)

BTEX 

Emission 

Factor

(lb/MMscfppmv)

Equivalent 

BTEX 

Emissions 

determined 

by Revised 

Limit (tpy)8B T E X B T E X Total

C IV-G-30, 

pg 8

1 155 2,139 0.234 0.326 0.008 0.253 0.957 1.337 0.034 1.036 3.364 35.0 3.40E-03 19.14

A IV-G-30, 

pg 12

1 155 1,769 0.111 0.154 0.004 0.120 0.547 0.764 0.019 0.592 1.922 20.0 3.40E-03 10.94

B IV-G-30, 

pg 10

1 155 2,013 0.189 0.263 0.007 0.204 0.821 1.146 0.029 0.888 2.884 30.0 3.40E-03 16.40

D IV-G-27, 

pg 8

1 20 8,760 0.993 1.972 0 0 0.993 1.972 0 0 2.965 120.0 6.77E-03 8.47

E IV-G-27, 

pg 10

1 20 8,760 0.816 1.588 0 0 0.816 1.588 0 0 2.404 60.0 1.10E-02 4.23

F IV-G-31, 

pg 19

1 24 8,760 0.525 1.594 0 3.659 0.525 1.594 0 3.659 5.777 50.0 2.64E-02 4.23

G IV-G-26, 

No. 1

1 29.98 8,760 0.389 0.731 0.667 0.970 0.389 0.731 0.667 0.970 2.757 12.5 4.03E-02 1.32

I IV-G-24, 

pg 9

1 24 4,380 0.240 0.454 0.066 0.332 0.480 0.907 0.132 0.664 2.183 5.7 8.75E-02 0.48

J IV-G-26, 

No. 2

1 40 8,760 0.275 0.491 0.391 1.648 0.275 0.491 0.391 1.648 2.805 7.0 5.49E-02 0.99

K IV-G-26, 

No. 3

1 49.98 8,760 1.182 2.235 0.974 1.182 1.182 2.235 0.974 1.182 5.573 7.0 8.73E-02 1.23

 

6

Facility ID corresponds to IDs presented in Impacts memo (Memorandum from Brown, Heather, EC/R Incorporated, to Moore, B. and Nizich, G., 

EPA/OAQPS/SPPD/FIG. July 28, 2011. Oil and Natural Gas Production MACT and Natural Gas Transmission and Storage MACT – Glycol Dehydrators: Impacts of 

MACT Review Options. Docket Number EPA-HQ-OAR-2010-0505-0047. Facility H was determined to be a large glycol dehydration unit when maximum 

operating parameters were used. Therefore, this facility was removed from the analysis.

7 BTEX emissions either provided by each company or calculated using GLYCalc Version 3.0 using the glycol dehydration unit operational data submitted. BTEX 

emissions were calculated for full-time operation by scaling up from reported operation.

8

Calculated using revised MACT limit of 1.93-2lb BTEX/MMscf-ppmv (revised using UPL variability) and each facility’s BTEX concentration and throughput.
APPENDIX A

A-4

Facility

ID No.6

Docket 

ID

No.

of 

Units

BTEX

Inlet 

Conc. 

(ppmv)

Reported 

hours of 

operation 

(hr/yr)

BTEX Emissions based on 

Reported Hours of Operation 

(tpy)7

BTEX Emissions based on Full Time 

Operation (tpy)7

Throughput 

(MMscf/D)

BTEX 

Emission 

Factor

(lb/MMscfppmv)

Equivalent 

BTEX 

Emissions 

determined 

by Revised 

Limit (tpy)8B T E X B T E X Total

L IV-G-26, 

No. 4

1 27 8,760 0.576 2.098 2.310 2.193 0.576 2.098 2.310 2.193 7.176 15.0 9.71E-02 1.43

M IV-G-26, 

No. 5

1 26 8760 0.569 2.055 2.245 2.116 0.569 2.055 2.245 2.116 6.985 15.0 9.81E-02 1.38

N IV-G-26, 

No. 6

1 29.94 8760 0.294 0.625 0.609 0.751 0.294 0.625 0.609 0.751 2.278 4.0 1.04E-01 0.42

O IV-G-26, 

No. 7

1 29.98 8760 0.295 0.532 0.441 0.525 0.295 0.532 0.441 0.525 1.794 3.0 1.09E-01 0.32

P IV-G-31, 

pg 27

1 34 8760 0.321 0.773 0 0.180 0.321 0.773 0 0.180 1.275 0.9 2.36E-01 0.10

15 Total number of units Avg of top 5 5.59E-03 11.84

5 Top 12% (five if less than 

30 units

Shaded cells represent facilities considered in the MACT floor.
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

1 (Dehydration NEI11215 GORDON GAS PROCESSING PLANT 7.54E+00 3.82E+00 UNCONTROLLED 95%

units with NEI11296 WHARTON GAS PLANT 4.05E+00 3.83E+00 UNCONTROLLED 95%

uncontrolled NEI12150 VIDOR PRODUCTION FACILITY 5.92E+00 5.83E+00 UNCONTROLLED 95.00%

benzene emissions NEI12443 EXPRO ENGINEERING 6.01E+00 5.97E+00 UNCONTROLLED 95.00%

greater than 1 tpy) NEI12443 EXPRO ENGINEERING 3.59E+00 3.56E+00 UNCONTROLLED 95%

NEI12474 J L DAVIS PEARSALL PLANT 3.27E+00 3.01E+00 UNCONTROLLED 95%

NEI12494 FAIN GAS PLANT 3.24E+01 2.10E+01 UNCONTROLLED 99.75%

NEI13135 NINE MILE PT CMPSR STATION 3.76E+00 3.67E+00 UNCONTROLLED 95%

NEI2CO0145 ENCANA OIL & GAS (USA) INC - PARK CANY 1.33E+01 1.33E+01 UNCONTROLLED 95.00%

NEI2CO045365 WILLIAMS PROD RMT CORP - PARACHUTE 4.71E+00 4.71E+00 UNCONTROLLED 95%

NEI2CO045366 ENCANA OIL & GAS (USA) INC - GASAWAY 1.48E+01 1.48E+01 UNCONTROLLED 95.00%

NEI2CO045366 ENCANA OIL & GAS (USA) INC - GASAWAY 1.05E+01 9.82E+00 UNCONTROLLED 95.00%

NEI2CO045368 ENCANA OIL & GAS (USA) INC - PUMBA 1.51E+01 1.40E+01 UNCONTROLLED 95.00%

NEI2CO045370 ENCANA GATHERING - MAMM CRK 

CONDITIONI

8.97E+00 8.97E+00 UNCONTROLLED 95.00%

NEI2CO045370 ENCANA GATHERING - MAMM CRK 

CONDITIONI

6.46E+00 2.85E+00 UNCONTROLLED 95%

NEI2TX14311 HUCKABAY GAS PLANT 5.75E+00 5.27E+00 UNCONTROLLED 95%

NEI2TX416 E LAKE CREEK COMPRESSOR 4.14E+00 3.96E+00 UNCONTROLLED 95%

NEI6476 BRECKENRIDGE BOOSTER STATION 1.23E+01 1.16E+01 UNCONTROLLED 95.00%

NEI6574 GIDDINGS PLANT 3.94E+00 3.94E+00 UNCONTROLLED 95%

NEI6597 CONGER GATHERING FACILITY 1.01E+01 5.35E+00 UNCONTROLLED 95%

NEI6956 CLAM LAKE COMPR STA 1 3.17E+00 2.87E+00 UNCONTROLLED 95%

NEI7417 SHACKELFORD PLANT 3.71E+00 3.58E+00 UNCONTROLLED 95%

NEI7511 MILLERS BEND COMP STN 1.59E+01 1.57E+01 UNCONTROLLED 95.00%

NEI7554 DARK CANYON COMPR STAT 1.13E+01 1.11E+01 UNCONTROLLED 95.00%

NEI7597 GRAHAM COMPRESSOR STATION 7.92E+00 7.80E+00 UNCONTROLLED 95.00%

NEI8001 VAN GASOLINE PLANT 19 6.53E+00 6.23E+00 UNCONTROLLED 95.00%

NEICO0090045 MIDSTREAM ENERGY - SPELUNKER CS 4.33E+01 4.28E+01 UNCONTROLLED 99.75%

NEICO0450077 CANYON GAS RESOURCES - RIFLE C S 6.64E+00 5.34E+00 UNCONTROLLED 95%

B-1
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEICO0450077 CANYON GAS RESOURCES - RIFLE C S 6.57E+00 6.57E+00 UNCONTROLLED 95.00%

NEICO0450077 CANYON GAS RESOURCES - RIFLE C S 7.07E+00 6.37E+00 UNCONTROLLED 95.00%

NEICO0450187 ENCANA - TRAIL RIDGE STA & 1-23 7.01E+00 7.01E+00 UNCONTROLLED 95.00%

NEICO0450187 ENCANA - TRAIL RIDGE STA & 1-23 1.78E+01 1.78E+01 UNCONTROLLED 95.00%

NEICO0450228 WILLIAMS PRODUCTION RMT CO - ROAN 

CLIFF

3.55E+00 3.55E+00 UNCONTROLLED 95%

NEICO1230057 KERR-MCGEE FT LUPTON COMPRESSOR 

STATION

5.54E+01 5.03E+01 UNCONTROLLED 99.75%

NEIOK1709 ATLAS PIPELINE MIDCONTINENT WESTOK 2.45E+00 2.19E+00 UNCONTROLLED 95%

NEIOK2002 ONEOK FIELD SVC 1.89E+01 1.77E+01 UNCONTROLLED 95.00%

NEITX115009S WELCH CO2 PLANT 1.57E+01 1.17E+01 UNCONTROLLED 95.00%

NEITXRHM0010 FAIRWAY GAS PLT 2.60E+00 2.60E+00 UNCONTROLLED 95%

NEITXRYB0046 GIBSON COMPRESSOR STATION 1.51E+01 1.47E+01 UNCONTROLLED 95.00%

Group 2 NEI11127 TAFT COMPRESSOR STATION 2.27E-01 2.05E-01 UNCONTROLLED 0%

(Dehydration units NEI11187 SAND HILLS PLANT 1.41E-03 9.39E-04 UNCONTROLLED 0%

with uncontrolled NEI11191 WQPUEBLO PLANT 1.29E-03 8.61E-04 UNCONTROLLED 0%

emissions less NEI11207 MCMULLEN COMPRESSOR STATION 7.11E-01 3.55E-01 UNCONTROLLED 0%

than 1 tpy) NEI11211 CONROE COMPRESSOR STATION 6.13E-03 4.08E-03 UNCONTROLLED 0%

NEI11215 GORDON GAS PROCESSING PLANT 5.42E+00 2.33E+00 UNCONTROLLED 95%

NEI11215 GORDON GAS PROCESSING PLANT 2.38E-03 1.58E-03 UNCONTROLLED 0%

NEI11239 PORT NECHES FIELD 1.88E-04 1.25E-04 UNCONTROLLED 0%

NEI11239 PORT NECHES FIELD 2.40E-01 2.40E-01 UNCONTROLLED 0%

NEI11296 WHARTON GAS PLANT 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEI11476 MAGNET WITHERS STATION 3.03E-01 3.03E-01 UNCONTROLLED 0%

NEI11594 MAGNET WITHERS COMP STATION 1.38E-03 9.18E-04 UNCONTROLLED 0%

NEI11594 MAGNET WITHERS COMP STATION 8.63E-02 7.62E-02 UNCONTROLLED 0%

NEI11771 NORTH POINT BOLIVAR FIELD 3.92E-05 2.61E-05 UNCONTROLLED 0%

NEI11924 MORGAN BLUFF FIELD 2.75E-04 1.83E-04 UNCONTROLLED 0%

NEI11926 PORTILLA GAS PLANT 6.90E-04 4.59E-04 UNCONTROLLED 0%

NEI11929 OYSTER BAYOU 6.28E-04 4.17E-04 UNCONTROLLED 0%

B-2
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI12032 NORTHWEST OZONA PLANT 9.21E-02 1.39E-02 UNCONTROLLED 0%

NEI12032 NORTHWEST OZONA PLANT 7.45E-04 4.96E-04 UNCONTROLLED 0%

NEI12032 NORTHWEST OZONA PLANT 1.27E-02 1.15E-02 UNCONTROLLED 0%

NEI12047 WASKOM GAS PLANT 3.67E-03 2.44E-03 UNCONTROLLED 0%

NEI12059 KARON PLANT 5.88E-04 3.91E-04 UNCONTROLLED 0%

NEI12059 KARON PLANT 8.87E-01 5.90E-01 UNCONTROLLED 0%

NEI12065 MANSFIELD COMPRESSOR STN 7.92E-01 7.30E-01 UNCONTROLLED 0%

NEI12079 PROSPECT COMPRESSOR STN 1.84E-01 1.65E-01 UNCONTROLLED 0%

NEI12088 FIG RIDGE CENTRAL 1.30E-03 6.00E-04 UNCONTROLLED 0%

NEI12150 VIDOR PRODUCTION FACILITY 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 2.53E-03 1.68E-03 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 7.00E-04 5.00E-04 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 1.30E-03 1.00E-03 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 2.68E-03 1.78E-03 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 4.55E-04 3.03E-04 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 9.41E-05 6.26E-05 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 2.04E-04 1.36E-04 UNCONTROLLED 0%

NEI12380 SHERMAN GAS PLANT 3.94E-03 2.62E-03 UNCONTROLLED 0%

NEI12425 POINT BARROW FACILITY 4.47E-04 2.97E-04 UNCONTROLLED 0%

NEI12443 EXPRO ENGINEERING 1.33E-04 8.87E-05 UNCONTROLLED 0%

NEI12443 EXPRO ENGINEERING 7.84E-05 5.22E-05 UNCONTROLLED 0%

NEI12470 MIDWAY LANE GAS PLANT 1.82E-03 1.21E-03 UNCONTROLLED 0%

NEI12470 MIDWAY LANE GAS PLANT 1.22E-03 8.14E-04 UNCONTROLLED 0%

NEI12474 J L DAVIS PEARSALL PLANT 3.69E-04 2.45E-04 UNCONTROLLED 0%

NEI12487 PEGASUS GAS PLANT 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEI12487 PEGASUS GAS PLANT 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEI12494 FAIN GAS PLANT 3.40E-03 2.26E-03 UNCONTROLLED 0%

NEI12504 KEYSTONE PLANT 5.10E-02 3.39E-02 UNCONTROLLED 0%

NEI13085 LAKE CREEK PLANT 6.28E-04 4.17E-04 UNCONTROLLED 0%

NEI13271 ALAZAN COMPRESSOR STATION 6.35E-04 4.22E-04 UNCONTROLLED 0%

B-3
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI2CO045365 WILLIAMS PROD RMT CORP - PARACHUTE 1.89E-01 1.89E-01 UNCONTROLLED 0%

NEI2CO045367 ENCANA OIL & GAS - HUNTER MESA 1.06E+00 1.06E+00 UNCONTROLLED 95%

NEI2CO045367 ENCANA OIL & GAS - HUNTER MESA 1.06E+00 1.06E+00 UNCONTROLLED 95%

NEI2CO045367 ENCANA OIL & GAS - HUNTER MESA 5.02E-01 5.02E-01 UNCONTROLLED 0%

NEI2CO045368 ENCANA OIL & GAS (USA) INC - PUMBA 1.62E+00 1.62E+00 UNCONTROLLED 95%

NEI2CO045370 ENCANA GATHERING - MAMM CRK 

CONDITIONI

5.02E-01 5.02E-01 UNCONTROLLED 0%

NEI2CO0552 KERR-MCGEE - PLATTEVILLE CS 2.16E+00 2.16E+00 UNCONTROLLED 95%

NEI2LA109024 ANADARKO E & P/CL & F NO 1 PF 9.37E-01 7.24E-01 UNCONTROLLED 0%

NEI2LA109024 ANADARKO E & P/CL & F NO 1 PF 1.25E+00 9.32E-01 UNCONTROLLED 0%

NEI2MIB9139 MERIT ENERGY CO. - BLAIR 36 CPF 1.63E+00 1.08E+00 UNCONTROLLED 95%

NEI2MIB9162 MERIT ENERGY CO. - MAYFIELD 19 CPF 6.15E-02 4.10E-02 UNCONTROLLED 0%

NEI2MIN6793 DTE GAS & OIL - CHESTER 16 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN6939 DTE GAS & OIL - OLD VANDY NORTH 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN6946 DTE GAS & OIL - OLD VANDY SOUTH 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN6999 KCS RESOURCES INC. MAYFIELD 28 9.04E-01 6.02E-01 UNCONTROLLED 0%

NEI2MIN7084 DTE GAS AND OIL COMPANY - BAGLEY 16 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7086 DTE GAS AND OIL COMPANY - WARNER 8 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7087 DTE GAS AND OIL COMPANY - WARNER 27 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7088 DTE GAS & OIL COMPANY - CUSTER 15/20 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7089 DTE GAS AND OIL COMPANY - JORDAN 12 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7090 DTE GAS AND OIL COMPANY - JORDAN 9 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7091 DTE GAS & OIL COMPANY - ECHO 26 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7093 DTE GAS AND OIL COMPANY - KEARNEY 9 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2MIN7094 DTE GAS & OIL COMPANY - CUSTER 33 CPF 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEI2TX03310 HANOVER REINECKE SITE 2.13E-01 1.42E-01 UNCONTROLLED 0%

NEI2TX039141 MANVEL FIELD CENTRAL COMPRESSOR 

STATION

6.82E-04 4.54E-04 UNCONTROLLED 0%

NEI2TX039141 MANVEL FIELD CENTRAL COMPRESSOR 

STATION

3.24E+00 2.88E+00 UNCONTROLLED 95%

B-4
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI2TX0711 ANAHUAC COMPRESSOR STATION 7.78E-01 5.17E-01 UNCONTROLLED 0%

NEI2TX07195 JACKSON HEIRS #1 PRODUCTION FACILITY 3.48E-01 2.99E-01 UNCONTROLLED 0%

NEI2TX101 GALVESTON ISLAND GATH STATION 6.28E-04 4.17E-04 UNCONTROLLED 0%

NEI2TX101 GALVESTON ISLAND GATH STATION 3.59E+00 6.67E-01 UNCONTROLLED 0%

NEI2TX101 GALVESTON ISLAND GATH STATION 2.50E+00 4.46E-01 UNCONTROLLED 0%

NEI2TX128 G.C.W.A. #1 PRODUCTION FACILITY 8.57E-02 8.57E-02 UNCONTROLLED 0%

NEI2TX1355 HANNA NASH FACILITY 1.12E+00 1.12E+00 UNCONTROLLED 95%

NEI2TX14311 HUCKABAY GAS PLANT 2.82E-03 1.88E-03 UNCONTROLLED 0%

NEI2TX1546 JOSEY RANCH 2, 4, 5 PRODUCTION FACILITY 4.00E-04 2.66E-04 UNCONTROLLED 0%

NEI2TX1546 JOSEY RANCH 2, 4, 5 PRODUCTION FACILITY 3.73E-02 3.73E-02 UNCONTROLLED 0%

NEI2TX1619 TEAGUE GAS PLANT 3.70E-03 2.46E-03 UNCONTROLLED 0%

NEI2TX211 CINCO LTD NO 1 FACILITY 1.65E+00 1.49E+00 UNCONTROLLED 95%

NEI2TX21136 GOAD-HEMPHILL COMPLEX 1.41E-03 9.39E-04 UNCONTROLLED 0%

NEI2TX21136 GOAD-HEMPHILL COMPLEX 9.68E-01 6.44E-01 UNCONTROLLED 0%

NEI2TX245668 HAYES KEITH #1 PRODUCTION FACILITY 2.41E+00 2.34E+00 UNCONTROLLED 95%

NEI2TX245668 HAYES KEITH #1 PRODUCTION FACILITY 1.80E-04 1.20E-04 UNCONTROLLED 0%

NEI2TX245668 HAYES KEITH #1 PRODUCTION FACILITY 5.25E-01 3.49E-01 UNCONTROLLED 0%

NEI2TX2613 ARMSTRONG COMPRESSOR STATION 1.43E-01 1.22E-01 UNCONTROLLED 0%

NEI2TX2615 CALANDRIA COMP STATION 5.18E-04 3.44E-04 UNCONTROLLED 0%

NEI2TX2615 CALANDRIA COMP STATION 1.48E+00 1.48E+00 UNCONTROLLED 95%

NEI2TX39132 LAKE PASTURE LP LEASE 6.99E+00 6.36E+00 UNCONTROLLED 95.00%

NEI2TX39132 LAKE PASTURE LP LEASE 6.38E+00 6.18E+00 UNCONTROLLED 95.00%

NEI2TX39132 LAKE PASTURE LP LEASE 1.57E-03 1.04E-03 UNCONTROLLED 0%

NEI2TX39132 LAKE PASTURE LP LEASE 1.57E-03 1.04E-03 UNCONTROLLED 0%

NEI2TX39139 TOM O'CONNER COMPRESSOR STATION 9.41E-04 6.26E-04 UNCONTROLLED 0%

NEI2TX39140 FANNIE HEARD LEASE 9.41E-04 6.26E-04 UNCONTROLLED 0%

NEI2TX39140 FANNIE HEARD LEASE 4.31E-02 2.87E-02 UNCONTROLLED 0%

NEI2TX39520 BOA GAS TREATING PLANT 1.04E-02 6.89E-03 UNCONTROLLED 0%

NEI2TX39913 SALLIE ODOM STATION 6.82E-04 4.54E-04 UNCONTROLLED 0%

NEI2TX39913 SALLIE ODOM STATION 1.39E-01 1.39E-01 UNCONTROLLED 0%

B-5
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI2TX40138 BUSBY CMPRSSR SAT 1.80E+00 1.79E+00 UNCONTROLLED 95%

NEI2TX416 E LAKE CREEK COMPRESSOR 2.98E-04 1.98E-04 UNCONTROLLED 0%

NEI2TX42343 PERRY COMP COMMON POINT 4.55E-02 3.03E-02 UNCONTROLLED 0%

NEI2TX42343 PERRY COMP COMMON POINT 1.03E-01 1.03E-01 UNCONTROLLED 0%

NEI2TX42343 PERRY COMP COMMON POINT 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEI2TX42343 PERRY COMP COMMON POINT 4.55E-02 3.03E-02 UNCONTROLLED 0%

NEI2TX4311 CONGER SALES FACILITY 2.04E-03 1.36E-03 UNCONTROLLED 0%

NEI2TX4311 CONGER SALES FACILITY 1.77E-01 1.48E-01 UNCONTROLLED 0%

NEI2TX669 BULLER LOCKE PRODUCTION FACILITY 5.66E-01 5.66E-01 UNCONTROLLED 0%

NEI2TX670 GUBERT NO. 1 PRODUCTION FACILITY 2.20E-04 1.46E-04 UNCONTROLLED 0%

NEI41887 PUCKETT COMPRESSOR STATION 1.58E-03 1.05E-03 UNCONTROLLED 0%

NEI42031 Bluebell Gas Plant 2.78E+00 9.73E-01 UNCONTROLLED 95%

NEI6439 LONGVIEW GAS PLANT 2.07E-03 1.38E-03 UNCONTROLLED 0%

NEI6439 LONGVIEW GAS PLANT 1.62E-03 1.08E-03 UNCONTROLLED 0%

NEI6442 TRINIDAD GAS PLT 7.99E-02 5.31E-02 UNCONTROLLED 0%

NEI6448 GIBTOWN COMPRESSOR STATN 6.58E-01 5.80E-01 UNCONTROLLED 0%

NEI6449 W RANCH COMP STA VANDERB 2.35E-03 1.56E-03 UNCONTROLLED 0%

NEI6453 EXXON MOBIL SARITA COMPRE 1.39E-03 9.23E-04 UNCONTROLLED 0%

NEI6453 EXXON MOBIL SARITA COMPRE 1.73E-03 1.15E-03 UNCONTROLLED 0%

NEI6461 SALE RANCH GAS PLANT 6.27E-02 2.77E-02 UNCONTROLLED 0%

NEI6461 SALE RANCH GAS PLANT 1.84E-03 1.22E-03 UNCONTROLLED 0%

NEI6476 BRECKENRIDGE BOOSTER STATION 6.90E-04 4.59E-04 UNCONTROLLED 0%

NEI6483 KATY GAS PLANT 2.26E-03 1.50E-03 UNCONTROLLED 0%

NEI6492 JAMESON GAS PLANT 9.26E-04 6.15E-04 UNCONTROLLED 0%

NEI6509 CANADIAN PLANT 1.65E-03 1.10E-03 UNCONTROLLED 0%

NEI6512 PAWNEE GAS PLANT 3.80E-03 2.53E-03 UNCONTROLLED 0%

NEI6512 PAWNEE GAS PLANT 2.77E-03 1.84E-03 UNCONTROLLED 0%

NEI6523 SONORA GAS PLANT NO 2 1.88E-01 1.18E-01 UNCONTROLLED 0%

NEI6597 CONGER GATHERING FACILITY 9.26E-04 6.15E-04 UNCONTROLLED 0%

NEI6602 WILLARD CO2 SEPARATION PLANT 2.35E-03 1.56E-03 UNCONTROLLED 0%

B-6
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI6603 CARGRAY PLANT 1.88E-03 1.25E-03 UNCONTROLLED 0%

NEI6603 CARGRAY PLANT 3.92E-01 2.61E-01 UNCONTROLLED 0%

NEI6752 BARTON CHAPEL PLANT 2.39E+00 2.10E+00 UNCONTROLLED 95%

NEI6752 BARTON CHAPEL PLANT 2.51E-04 1.67E-04 UNCONTROLLED 0%

NEI6752 BARTON CHAPEL PLANT 2.51E-04 1.67E-04 UNCONTROLLED 0%

NEI6948 HUMBLE COMMON STORAGE 9.29E-01 6.12E-01 UNCONTROLLED 0%

NEI6948 HUMBLE COMMON STORAGE 6.28E-05 4.17E-05 UNCONTROLLED 0%

NEI6956 CLAM LAKE COMPR STA 1 3.92E-04 2.61E-04 UNCONTROLLED 0%

NEI6957 NELEH GAS PLANT 9.31E-02 9.31E-02 UNCONTROLLED 0%

NEI6957 NELEH GAS PLANT 4.63E-04 3.08E-04 UNCONTROLLED 0%

NEI6964 IRION PLANT 6.51E-04 4.33E-04 UNCONTROLLED 0%

NEI6964 IRION PLANT 2.50E-02 2.50E-02 UNCONTROLLED 0%

NEI6965 CHERRYHOMES CMPRSSR STN 2.78E+00 2.63E+00 UNCONTROLLED 95%

NEI7311 DECATUR COMPRESSOR STATION 1.38E+00 1.32E+00 UNCONTROLLED 95%

NEI7380 HAMLIN GAS PLANT 6.12E-02 4.07E-02 UNCONTROLLED 0%

NEI7410 SPRINGTOWN GAS PLANT 2.41E-03 1.60E-03 UNCONTROLLED 0%

NEI7410 SPRINGTOWN GAS PLANT 2.41E-03 1.60E-03 UNCONTROLLED 0%

NEI7417 SHACKELFORD PLANT 9.33E-04 6.21E-04 UNCONTROLLED 0%

NEI7421 VIBORES COMPRESSOR STATION 3.53E-04 2.35E-04 UNCONTROLLED 0%

NEI7421 VIBORES COMPRESSOR STATION 9.48E-02 6.30E-02 UNCONTROLLED 0%

NEI7426 LULING GAS PLANT 4.60E-02 3.06E-02 UNCONTROLLED 0%

NEI7428 SCHAFER FACILITY 1.33E-03 8.87E-04 UNCONTROLLED 0%

NEI7428 SCHAFER FACILITY 8.24E-02 8.24E-02 UNCONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT 5.57E-04 3.70E-04 UNCONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT 9.26E-04 6.15E-04 UNCONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT 9.26E-04 6.15E-04 UNCONTROLLED 0%

NEI7449 BRAZORIA NATURAL GAS BOOSTER 7.61E-04 5.06E-04 UNCONTROLLED 0%

NEI7449 BRAZORIA NATURAL GAS BOOSTER 2.82E-04 1.88E-04 UNCONTROLLED 0%

NEI7454 BRANNON COMPRESSOR 8.46E-01 7.96E-01 UNCONTROLLED 0%

NEI7493 NONA MILLS C & W 7.44E-01 7.44E-01 UNCONTROLLED 0%

B-7
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI7499 PERRIN COMPRESSOR STATION 4.17E-01 3.64E-01 UNCONTROLLED 0%

NEI7554 DARK CANYON COMPR STAT 2.43E-04 1.62E-04 UNCONTROLLED 0%

NEI7578 CLEAR LAKE GAS PLANT 1.35E+00 1.21E+00 UNCONTROLLED 95%

NEI7599 LIQUID SEPARATION PLANT (MILSP) 3.14E-03 2.09E-03 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) 2.35E-03 1.56E-03 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) 2.12E-02 1.41E-02 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) 8.68E-02 5.77E-02 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) 8.77E-02 5.83E-02 UNCONTROLLED 0%

NEI7751 SNEED PLANT 5.89E-02 3.91E-02 UNCONTROLLED 0%

NEI7785 OYSTER LAKE FACILITY 3.17E-01 3.17E-01 UNCONTROLLED 0%

NEI7785 OYSTER LAKE FACILITY 3.17E-01 3.17E-01 UNCONTROLLED 0%

NEI7785 OYSTER LAKE FACILITY 9.40E-01 9.40E-01 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN 6.82E-04 4.54E-04 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN 6.82E-04 4.54E-04 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN 6.82E-04 4.54E-04 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN 2.55E-01 1.70E-01 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN 2.55E-01 1.70E-01 UNCONTROLLED 0%

NEI7839 TRAWICK WEST STATION 5.02E-04 3.34E-04 UNCONTROLLED 0%

NEI7839 TRAWICK WEST STATION 6.79E-02 4.52E-02 UNCONTROLLED 0%

NEI7844 GULF COAST FRACTIONATORS 4.53E-01 4.08E-01 UNCONTROLLED 0%

NEI7978 EAST VEALMOOR GAS PLANT 4.00E-01 3.60E-01 UNCONTROLLED 0%

NEI7990 EAST TEXAS GAS PLANT 6.72E-03 4.47E-03 UNCONTROLLED 0%

NEI7992 BIG LAKE PLANT 6.38E-02 6.38E-02 UNCONTROLLED 0%

NEI7992 BIG LAKE PLANT 4.63E-04 3.08E-04 UNCONTROLLED 0%

NEI7992 BIG LAKE PLANT 4.63E-04 3.08E-04 UNCONTROLLED 0%

NEI7998 SONORA GAS PLANT 1.57E-03 1.04E-03 UNCONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 2.05E-02 1.36E-02 UNCONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 1.47E-03 9.81E-04 UNCONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 3.26E-03 2.16E-03 UNCONTROLLED 0%

NEI8017 NONA MILLS TRACT 185 1.69E+00 1.69E+00 UNCONTROLLED 95%

B-8
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI8019 WIZARD WELLS CMPRSR STN 1.76E+00 9.45E-01 UNCONTROLLED 0%

NEI8145 EAST CHICO COMPRESSOR STATION 9.26E-04 6.15E-04 UNCONTROLLED 0%

NEI8145 EAST CHICO COMPRESSOR STATION 1.24E+00 1.20E+00 UNCONTROLLED 95%

NEICO0186 CALPINE NATURAL GAS COMPANY-MAMM 

CREEK

1.46E-01 1.46E-01 UNCONTROLLED 0%

NEICO0186 CALPINE NATURAL GAS COMPANY-MAMM 

CREEK

9.60E-02 9.60E-02 UNCONTROLLED 0%

NEICO0450077 CANYON GAS RESOURCES - RIFLE C S 2.66E+00 2.66E+00 UNCONTROLLED 95%

NEICO1030036 ENCANA OIL & GAS (USA) INC-DRAGON 

TRAIL

1.26E-02 8.35E-03 UNCONTROLLED 0%

NEICO1230057 KERR-MCGEE FT LUPTON COMPRESSOR 

STATION

1.33E-01 1.33E-01 UNCONTROLLED 0%

NEICO1230277 DUKE ENERGY FIELD SERVICES - 1.94E+00 1.94E+00 UNCONTROLLED 95%

NEILA00702000047 LINDER OIL CO/WILLIAMS JEANERETTE L&S 

FACILITY

8.63E-01 5.74E-01 UNCONTROLLED 0%

NEILA0123 GULFPORT ENERGY CORP/W COTE 

BLANCHE BAY DEHY

7.84E-02 5.22E-02 UNCONTROLLED 0%

NEILA01504000046 HUNT PETROLEUM CORP/SLIGO FIELD 

CENTRAL FACILITY

1.57E-01 1.04E-01 UNCONTROLLED 0%

NEILA04512600052 APACHE CORP/BAYOU PIGEON FIELD 

CENTRAL FACILITY

7.84E-02 5.22E-02 UNCONTROLLED 0%

NEILA04512600110 LINDER OIL CO/KYLE PETERMAN 

MANAGEMENT CORP PRODUCTION 

7.84E-02 5.22E-02 UNCONTROLLED 0%

NEILA04712800116 SOUTHERN BAY OPERATING LLC/SCHWING 

10 PROD FAC - FROG LAKE FIELD

3.14E-01 2.09E-01 UNCONTROLLED 0%

NEILA0750034 XPLOR ENERGY OPERATING CO/MAIN PASS 

BOCLK 35 CENTRAL FACILITY

1.57E-01 1.04E-01 UNCONTROLLED 0%

NEILA07522400241 APACHE CORP/SOUTHEAST PASS 

COMMON FACILITY #2

1.57E-01 1.04E-01 UNCONTROLLED 0%

B-9
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEILA09325600076 HENRY PRODUCTION COMPANY/MILES 

TIMBER S22 D #1 PROD FAC - LOWER 

VACHERIE FIELD

6.28E-01 4.17E-01 UNCONTROLLED 0%

NEILA09926200028 CHAPARRAL ENERGY INC/WILBERTS & 

SONS #1 PRODUCTION FACILITY

1.57E-01 1.04E-01 UNCONTROLLED 0%

NEILA09926200079 GOODRICH PETROLEUM CO LLC/PLUMB 

BOB FIELD CENTRAL FACILITY

2.35E-01 1.56E-01 UNCONTROLLED 0%

NEILA13712 HILCORP ENERGY CO/S PASS 24 FACILITY #2 7.84E-02 5.22E-02 UNCONTROLLED 0%

NEIMI001N6860 SAVOY ENERGY LP 3.61E-02 2.41E-02 UNCONTROLLED 0%

NEIMI001N6860 SAVOY ENERGY LP 3.61E-02 2.41E-02 UNCONTROLLED 0%

NEIMI001N7470 PETROLEUM DEVELOPMENT INC 5.40E-03 3.60E-03 UNCONTROLLED 0%

NEIMI001N7470 PETROLEUM DEVELOPMENT INC 5.40E-03 3.60E-03 UNCONTROLLED 0%

NEIMI007N624 HRF EXPLORATION AND PRODUCTION INC 2.70E-03 1.80E-03 UNCONTROLLED 0%

NEIMI007N7453 QUICKSILVER RESOURCES - BRADY 

BUNCH/LITTLE RASCALS

7.82E-04 5.22E-04 UNCONTROLLED 0%

NEIMI007N7462 QUICKSILVER RESOURCES INC.-BLUE 

HERRON/JACK SPRATT

7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI007N7472 QUICKSILVER RESOURCES - CARBON BLACK 

ROHMAN EMPIRE

7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI0096050 DTE GAS AND OIL COMPANY - HAWK LAKE 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI0096055 DTE GAS AND OIL COMPANY - JORDAN 35 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI009N7455 QUICKSILVER RESOURCES INC - ALL STATE 

STAR

7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI009N7457 QUICKSILVER RESOURCES INC. - 

MANCELONA 8

1.33E-03 8.87E-04 UNCONTROLLED 0%

NEIMI055B915 MERIT ENERGY CO. - GRANT 29 1.63E-01 1.08E-01 UNCONTROLLED 0%

NEIMI055N6501 FEDERATED OIL & GAS PROPERTIES 9.04E-01 6.02E-01 UNCONTROLLED 0%

NEIMI055N7037 MERIT ENERGY L P ST GRANT 1-16 4.70E-02 3.13E-02 UNCONTROLLED 0%

NEIMI057N5570 NEW HAVEN COMPRESSOR STATION 3.16E-01 2.11E-01 UNCONTROLLED 0%

NEIMI079B756 KCS RESOURCES, INC. GOOSE CREEK GSF 9.04E-01 6.02E-01 UNCONTROLLED 0%

B-10
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEIMI079N2455 QUICKSILVER RESOURCES INC. - KALKASKA 

1-21 CPF

7.23E-01 4.82E-01 UNCONTROLLED 0%

NEIMI079N7092 DTE GAS & OIL COMPANY - CLEARWATER 2 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI079N7409 QUICKSILVER RESOURCES INC. - PDC 

BOOSTER

3.57E-01 2.38E-01 UNCONTROLLED 0%

NEIMI107N632 CATO GLENWOOD FACILITY 1.37E-01 9.11E-02 UNCONTROLLED 0%

NEIMI1196155 DOMINION MIDWEST ENERGY, WEST 

ALBERT 11 PROD. FAC.

3.91E-05 2.61E-05 UNCONTROLLED 0%

NEIMI1196192 MUSKEGON DEVELOPMENT, MITCHEL LAKE 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1196193 MUSKEGON DEVELOPMENT, BIG WOLF 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI119N7252 HRF EXPLORATION & PRODUCTION 5.40E-03 3.60E-03 UNCONTROLLED 0%

NEIMI119N7454 QUICKSILVER RESOURCES INC - CATTLE 

ANTRIM

5.09E-04 3.39E-04 UNCONTROLLED 0%

NEIMI119N7459 QUICKSILVER RESOURCES INC. - PLEASANT 

VALLEY

7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI119N7467 QUICKSILVER RESOURCES INC. - HUNT N 

HAYES

7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI135N7463 QUICKSILVER RESOURCES INC. - ELMER 

FUDD EAST

1.76E-03 1.17E-03 UNCONTROLLED 0%

NEIMI1375933 ENER VEST OPERATING 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1375934 ENER VEST OPERATION 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1376052 DTE GAS AND OIL COMPANY - WARNER 22 

CPF

2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376054 DTE GAS & OIL COMPANY - ELMIRA 14 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376057 DTE GAS AND OIL COMPANY - WARNER 13 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376058 DTE GAS AND OIL COMPANY - WARNER 10 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376079 PAXTON RESOURCES, LIVINGSTON 18 CPF 8.22E-04 5.48E-04 UNCONTROLLED 0%

NEIMI1376082 WARD LAKE ENERGY, CHARLTON 11/12, 

VIENNA 18 CPF

9.00E-04 6.00E-04 UNCONTROLLED 0%

B-11
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEIMI1376082 WARD LAKE ENERGY, CHARLTON 11/12, 

VIENNA 18 CPF

9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1376094 WARD LAKE ENERGY, CHESTER 23 CPF 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1376181 WARD LAKE ENERGY, CHARLTON 7 CPF 6.65E-04 4.43E-04 UNCONTROLLED 0%

NEIMI1376185 ANTRIM DEVELOPMENT CORP - TOWER 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376186 MUSKEGON DEVELOPMENT, PERCH LAKE 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376187 MUSKEGON DEVELOPMENT, NO LAKE 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376188 MUSKEGON DEVELOPMENT, LITTLE CRAPO 

LAKE

2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376189 MUSKEGON DEVELOPMENT, LOWER CHUB 

LAKE/VIKING LAKE

2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376189 MUSKEGON DEVELOPMENT, LOWER CHUB 

LAKE/VIKING LAKE

2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376190 MUSKEGON DEVELOPMENT, CRAPO LAKE 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376191 MUSKEGON DEVELOPMENT, BASS LAKE 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI1376221 WARD LAKE ENERGY, CHARLTON 18 - CPF 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1376277 ENERVEST OPERATING 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1376278 ENER VEST OPERATING 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1376443 ENER VEST OPERATING 3.91E-05 2.61E-05 UNCONTROLLED 0%

NEIMI1376444 ENER VEST OPERATING 6.65E-04 4.43E-04 UNCONTROLLED 0%

NEIMI1376445 ENER VEST OPERATRING 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI1376446 ENER VEST OPERATING 3.91E-05 2.61E-05 UNCONTROLLED 0%

NEIMI137B566 KCS RESOURCES, INC. - OTSEGO 6 CPF 3.25E-02 2.17E-02 UNCONTROLLED 0%

NEIMI137B915 MERIT ENERGY CO.- HAYES 22 CPF 7.23E-01 4.82E-01 UNCONTROLLED 0%

NEIMI137N596 KCS RESOURCES, INC. OTSEGO LAKE 26 CPF 7.23E-01 4.82E-01 UNCONTROLLED 0%

NEIMI137N6099 WARD LAKE ENERGY, LIVINGSTON 34 6.65E-04 4.43E-04 UNCONTROLLED 0%

NEIMI137N621 WARD LAKE ENERGY, CHARLTON 24 - CPF 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI137N632 DTE GAS & OIL COMPANY - ELMIRA 23 2.39E-03 1.59E-03 UNCONTROLLED 0%

NEIMI137N6744 QUICKSILVER RESOURCES INC. - 

FONTINALIS 25

2.43E-03 1.62E-03 UNCONTROLLED 0%

B-12
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEIMI137N7015 QUICKSILVER RESOURCES INC. - ECHO LAKE 

6 CPF

7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI137N7065 QUICKSILVER RESOURCES INC. - NADV 1-2- 7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI137N7184 WARD LAKE ENERGY 9.78E-04 6.52E-04 UNCONTROLLED 0%

NEIMI137N7284 OIL ENERGY CORP. 3.09E-03 2.06E-03 UNCONTROLLED 0%

NEIMI137N7341 SCHMUDE OIL INC. 9.00E-04 6.00E-04 UNCONTROLLED 0%

NEIMI137N7435 ENER VEST OPERATING 3.91E-05 2.61E-05 UNCONTROLLED 0%

NEIMI137N7456 QUICKSILVER RESOURCES INC - LUCKY 16 5.87E-04 3.91E-04 UNCONTROLLED 0%

NEIMI137N7458 QUICKSILVER RESOURCES INC - NADV 7 5.87E-04 3.91E-04 UNCONTROLLED 0%

NEIMI137N7465 QUICKSILVER RESOURCES-HAYES 34 AKA 

GRIDIRON SEC 34

1.88E-03 1.25E-03 UNCONTROLLED 0%

NEIMI137N7466 QUICKSILVER RESOURCES INC. - WINTER 

ANTRIM

7.04E-04 4.69E-04 UNCONTROLLED 0%

NEIMI137N7488 ENER VEST OPERATING LLC 6.65E-04 4.43E-04 UNCONTROLLED 0%

NEIMI14392 MERIT ENERGY CO. - OTSEGO LAKE 34 2.35E-02 1.57E-02 UNCONTROLLED 0%

NEIMI2607942 MERIT ENERGY CO. - KALKASKA GAS PLANT 5.02E-02 3.34E-02 UNCONTROLLED 0%

NEIMIB5587 MERIT ENERGY COMPANY. - MAYFIELD 23 8.13E-02 5.42E-02 UNCONTROLLED 0%

NEIMIB9135 MERIT ENERGY CO. - BEAR LAKE 13 1.37E-01 9.16E-02 UNCONTROLLED 0%

NEIMIB9136 MERIT ENERGY CO. - BEAR LAKE 22 3.80E-01 2.53E-01 UNCONTROLLED 0%

NEIMIB9142 MERIT ENERGY COMPANY - CHARLTON 12 7.59E-02 5.06E-02 UNCONTROLLED 0%

NEIMIB9144 MERIT ENERGY COMPANY - CHARLTON 4 1.08E-01 7.23E-02 UNCONTROLLED 0%

NEIMIB9160 MERIT ENERGY COMPANY - MAPLE GROVE 

16

1.77E-01 1.18E-01 UNCONTROLLED 0%

NEIMIN0539 SUMMIT PETROLEUM CORP - ROSEBUSH 

GAS PLANT

1.50E-01 1.00E-01 UNCONTROLLED 0%

NEIMIN0686 STONEY POINT GAS PLANT 1.90E+00 1.26E+00 UNCONTROLLED 95%

NEIMIN5949 WHITE LAKE PRODUCTION FACILITY 1.74E+00 1.16E+00 UNCONTROLLED 95%

NEIMIN6015 PARTELLO COMPRESSOR STATION 7.77E-02 5.17E-02 UNCONTROLLED 0%

NEIMIN6015 PARTELLO COMPRESSOR STATION 3.12E-02 2.07E-02 UNCONTROLLED 0%

NEIMIN6100 DTE GAS & OIL - CUSTER ANTRIM CO2 2.39E-03 1.59E-03 UNCONTROLLED 0%

B-13
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEIMIN6159 DART OIL & GAS CORP 2.81E-01 1.87E-01 UNCONTROLLED 0%

NEIMIN6160 DART OIL & GAS CORP 1.75E-01 1.16E-01 UNCONTROLLED 0%

NEIMIN6161 DART OIL & GAS CORP 3.79E-02 2.53E-02 UNCONTROLLED 0%

NEIMIN6473 MERIT ENERGY COMPANY - ALBERT 25 CPF 1.92E-03 1.28E-03 UNCONTROLLED 0%

NEIOK2089 MADILL GAS PROCESSING LLC 3.22E+00 2.14E+00 UNCONTROLLED 95%

NEIOK2523 ONEOK FIELD SVC 1.04E+00 3.51E-01 UNCONTROLLED 0%

NEIOK2529 ONEOK FIELD SVC 7.06E-04 4.69E-04 UNCONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEIOK2720 ATLAS PIPELINE MIDCONTINENT WESTOK 1.57E-03 1.04E-03 UNCONTROLLED 0%

NEITX003AB00 DOLLARHIDE GAS PLANT 2.53E-03 1.68E-03 UNCONTROLLED 0%

NEITX039216U MCFARLAND FACILITY 3.21E-01 3.14E-01 UNCONTROLLED 0%

NEITX039216U MCFARLAND FACILITY 3.77E-04 2.50E-04 UNCONTROLLED 0%

NEITX039674 HASTINGS WEST COMPRESSOR STATION 2.35E-03 1.56E-03 UNCONTROLLED 0%

NEITX039675 HASTINGS CENTRAL COMPRESSOR 2.35E-03 1.56E-03 UNCONTROLLED 0%

NEITX039676 HASTINGS SOUTH COMPRESSOR STATION 2.35E-03 1.56E-03 UNCONTROLLED 0%

NEITX039682 BROCKMAN TANK BATTERY 5.62E-02 3.74E-02 UNCONTROLLED 0%

NEITX039682 BROCKMAN TANK BATTERY 8.63E-04 5.74E-04 UNCONTROLLED 0%

NEITX039692 WEST ANKENMAN SALES POINT 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEITX067CG00 MCLEOD GAS PLANT 1.25E-01 1.20E-01 UNCONTROLLED 0%

NEITX089CR00 HOUSTON CENTRAL GAS PLANT 2.35E-02 1.56E-02 UNCONTROLLED 0%

NEITX089CR00 HOUSTON CENTRAL GAS PLANT 3.45E-02 2.30E-02 UNCONTROLLED 0%

NEITX089CR00 HOUSTON CENTRAL GAS PLANT 2.43E-02 1.62E-02 UNCONTROLLED 0%

NEITX105012K TIPPETT PLANT 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEITX115009S WELCH CO2 PLANT 1.18E-03 7.82E-04 UNCONTROLLED 0%

NEITX161629 BUFFALO CENTRAL GATHERING 1.24E-02 8.24E-03 UNCONTROLLED 0%

NEITX161629 BUFFALO CENTRAL GATHERING 1.24E-02 8.24E-03 UNCONTROLLED 0%

NEITX167130 ALTA LOMA COMPRESSOR STATION 8.16E-04 5.42E-04 UNCONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT 4.50E-03 2.99E-03 UNCONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT 7.21E-01 4.79E-01 UNCONTROLLED 0%

B-14
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEITX18630 SALT CREEK FIELD GAS PLANT 5.40E-03 3.59E-03 UNCONTROLLED 0%

NEITX201972B NORTH MILTON 6.04E-04 4.02E-04 UNCONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT 0.00E+00 0.00E+00 UNCONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT 3.14E-03 2.09E-03 UNCONTROLLED 0%

NEITX245676 DOORNBOS A #1 PRODUCTION FACILITY 2.20E-04 1.46E-04 UNCONTROLLED 0%

NEITX245676 DOORNBOS A #1 PRODUCTION FACILITY 4.59E-01 3.05E-01 UNCONTROLLED 0%

NEITX25150 HAYS COMPRESSOR STATION 4.00E-04 2.66E-04 UNCONTROLLED 0%

NEITX25152 MEADOWS COMPRESSOR SITE 9.41E-05 6.26E-05 UNCONTROLLED 0%

NEITX25152 MEADOWS COMPRESSOR SITE 2.82E-04 1.88E-04 UNCONTROLLED 0%

NEITX25154 JOHNSON COUNTY COMPRESSOR STATION 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEITX25154 JOHNSON COUNTY COMPRESSOR STATION 1.72E-01 1.14E-01 UNCONTROLLED 0%

NEITX285067U NORTH WORD GAS PLANT 3.92E-04 2.61E-04 UNCONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT 6.28E-03 4.17E-03 UNCONTROLLED 0%

NEITX371019J GREY RANCH TREATING PLANT 1.13E+01 1.13E+01 UNCONTROLLED 95.00%

NEITX393010G NW MENDOTA GAS PLANT 6.73E-01 6.73E-01 UNCONTROLLED 0%

NEITX393010G NW MENDOTA GAS PLANT 4.94E-04 3.29E-04 UNCONTROLLED 0%

NEITX393010G NW MENDOTA GAS PLANT 1.14E-02 7.56E-03 UNCONTROLLED 0%

NEITX42345 ARNOLD 2 1 CENTRAL PRODUCTION 

FACILITY

3.14E-04 2.09E-04 UNCONTROLLED 0%

NEITX461001M CRANE GAS PLANT 2.48E-03 1.65E-03 UNCONTROLLED 0%

NEITX461002K WILSHIRE PLANT 1.38E-03 9.18E-04 UNCONTROLLED 0%

NEITX461006C BENEDUM GAS PLANT 4.71E-04 3.13E-04 UNCONTROLLED 0%

NEITX461058G NORTH CROSS COMP STATION4 1.57E-03 1.04E-03 UNCONTROLLED 0%

NEITX483254 ZYBACH CRYOGENIC PLANT 1.14E-03 7.56E-04 UNCONTROLLED 0%

NEITX483254 ZYBACH CRYOGENIC PLANT 9.20E-03 6.12E-03 UNCONTROLLED 0%

NEITXRAB0012 FULLERTON GAS PLANT 7.77E-02 5.16E-02 UNCONTROLLED 0%

NEITXRAB0012 FULLERTON GAS PLANT 1.57E-03 1.04E-03 UNCONTROLLED 0%

NEITXRBL0026 PLEDGER FACILITY 1.88E-04 1.25E-04 UNCONTROLLED 0%

NEITXRBL0026 PLEDGER FACILITY 2.93E+00 2.87E+00 UNCONTROLLED 95%

B-15
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEITXRGJ0139 WILLOW SPRINGS PLANT 2.67E-03 1.77E-03 UNCONTROLLED 0%

NEITXRHE0012 CONLEY PLANT 7.22E-03 4.80E-03 UNCONTROLLED 0%

NEITXRHG4368 DURKEE FIELD 5.86E-01 5.57E-01 UNCONTROLLED 0%

NEITXRJF0027 KINDER MORGAN TEXAS PIPELINE CO 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEITXRJF0027 KINDER MORGAN TEXAS PIPELINE CO 1.51E-03 1.00E-03 UNCONTROLLED 0%

NEITXRNE0062 FLOUR BLUFF STATION 4.85E+00 4.78E+00 UNCONTROLLED 95%

NEITXRNE0062 FLOUR BLUFF STATION 7.84E-06 5.22E-06 UNCONTROLLED 0%

NEITXRPE0020 PIKES PEAK PLANT 6.20E-03 4.12E-03 UNCONTROLLED 0%

NEITXRPE0020 PIKES PEAK PLANT 2.55E+00 1.69E+00 UNCONTROLLED 95%

NEITXRPE0042 COYANOSA GAS PLANT 4.39E-02 2.92E-02 UNCONTROLLED 0%

NEITXRSQ0088 JUNO COMPRESSOR STATION 2.35E-03 1.56E-03 UNCONTROLLED 0%

NEITXRTC0002 TERRELL GAS PLANT 4.71E-03 3.13E-03 UNCONTROLLED 0%

NEITXRTC0002 TERRELL GAS PLANT 4.22E-02 2.81E-02 UNCONTROLLED 0%

NEITXRWG0011 KELLERVILLE COMPRESSOR STATION 1.41E-03 9.39E-04 UNCONTROLLED 0%

NEITXRWN0107 ASHE COMPRESSOR STATION 1.35E+00 1.28E+00 UNCONTROLLED 95%

NEITXRWN0183 SITZ COMPRESSOR STATION 3.74E-03 2.49E-03 UNCONTROLLED 0%

Group 3 NEI11208 MIDLAND GAS PLT 6.82E-02 4.53E-02 CONTROLLED 0%

(Dehydration units NEI11771 NORTH POINT BOLIVAR FIELD 1.31E-02 8.68E-03 CONTROLLED 0%

with controlled NEI11921 WHELAN SOUTH COMP STA 8.43E-02 5.60E-02 CONTROLLED 0%

benzene emissions NEI11924 MORGAN BLUFF FIELD 2.13E-02 2.13E-02 CONTROLLED 0%

less than 0.05 tpy) NEI11929 OYSTER BAYOU 1.08E-01 1.04E-01 CONTROLLED 0%

NEI11929 OYSTER BAYOU 1.06E-01 1.02E-01 CONTROLLED 0%

NEI12270 HANKAMER 1.61E-01 1.55E-01 CONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING 8.63E-05 5.74E-05 CONTROLLED 0%

NEI12425 POINT BARROW FACILITY 1.10E-03 1.00E-03 CONTROLLED 0%

NEI12470 MIDWAY LANE GAS PLANT 2.78E-02 1.85E-02 CONTROLLED 0%

NEI13106 OZONA GAS PLANT 2.17E-02 1.67E-02 CONTROLLED 0%

NEI2OK285 DCP MIDSTREAM LP 1.49E-01 9.91E-02 CONTROLLED 0%

NEI2TX07156 C-2 PLATFORM 2.00E-04 2.00E-04 CONTROLLED 0%

NEI2TX07186 UMBRELLA POINT--TRINITY BAY 5.91E-02 4.52E-02 CONTROLLED 0%

B-16
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEI2TX16133 FREESTONE CENTRAL COMPRES 3.22E-04 2.14E-04 CONTROLLED 0%

NEI2TX1619 TEAGUE GAS PLANT 2.37E-02 1.58E-02 CONTROLLED 0%

NEI6094 CHEVRON USA INC/DELTA DUCK STN 1 7.48E-01 7.16E-01 CONTROLLED 0%

NEI6449 W RANCH COMP STA VANDERB 5.00E-04 5.00E-04 CONTROLLED 0%

NEI6449 W RANCH COMP STA VANDERB 3.69E-04 2.45E-04 CONTROLLED 0%

NEI6456 KING RANCH PLANT 4.17E-03 2.77E-03 CONTROLLED 0%

NEI6456 KING RANCH PLANT 4.60E-03 3.06E-03 CONTROLLED 0%

NEI6483 KATY GAS PLANT 4.74E-02 3.15E-02 CONTROLLED 0%

NEI6512 PAWNEE GAS PLANT 5.87E-02 5.77E-02 CONTROLLED 0%

NEI6855 AKER PLANT 9.00E-02 8.00E-02 CONTROLLED 0%

NEI7375 FASHING PLANT 9.00E-04 8.00E-04 CONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT 9.80E-02 9.80E-02 CONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT 6.30E-02 6.30E-02 CONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT 6.30E-02 6.30E-02 CONTROLLED 0%

NEI7500 GORDIN ESTATES COMPR FAC 6.00E-04 5.00E-04 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 2.25E-02 2.02E-02 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 1.50E-01 3.74E-02 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 2.57E-02 1.71E-02 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 2.20E-04 1.46E-04 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT 8.63E-05 5.74E-05 CONTROLLED 0%

NEICA0592079 UNION OIL CO OF CALIFORNIA (SI 7.16E-05 2.23E-05 CONTROLLED 0%

NEICA0592118 AERA ENERGY LLC 6.54E-05 6.54E-05 CONTROLLED 0%

NEICA0592118 AERA ENERGY LLC 2.44E-04 2.43E-04 CONTROLLED 0%

NEICO0186 CALPINE NATURAL GAS COMPANYMAMM CREEK6.91E+00 6.25E+00 CONTROLLED 95%

NEILA00702000046 PETRO-HUNT LLC/RAMOS INVESTMENTS #1 

FACILITY

7.84E-02 5.22E-02 CONTROLLED 0%

NEILA00702000048 CHAPARRAL ENERGY INC/J. AARON NO 2 

PRODUCTION FACILITY

2.35E-01 1.56E-01 CONTROLLED 0%

B-17
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEILA0075 STONE ENERGY CORP/LAFITTE FIELD 

COMPRESSOR STATION TB #5 & CAMP

1.45E+00 1.30E+00 CONTROLLED 95%

NEILA0098 LA LAND & EXPLOR - E LAKE SAND 1.60E-02 1.55E-02 CONTROLLED 0%

NEILA0123 GULFPORT ENERGY CORP/W COTE 

BLANCHE BAY DEHY

1.16E+00 9.94E-01 CONTROLLED 95%

NEILA0450042 SOURCE PETROLEUM INC/FAUSSE PT CS 2 1.89E+00 1.77E+00 CONTROLLED 95%

NEILA1010013 CABOT OIL & GAS CORP/BELLE ISLE BAT #1 2.18E-01 1.64E-01 CONTROLLED 0%

NEILA2210126600130 SWIFT ENERGY OPERATING LLC/COTE 

BLANCHE ISLAND TANK BATTERY #2

7.84E-02 5.22E-02 CONTROLLED 0%

NEIMI14392 MERIT ENERGY CO. - OTSEGO LAKE 34 4.50E-02 3.58E-02 CONTROLLED 0%

NEIMIN6468 QUICKSILVER RESOURCES INC - USA 

KALKASKA 3-20

3.97E-03 3.15E-03 CONTROLLED 0%

NEIMIN6473 MERIT ENERGY COMPANY - ALBERT 25 CPF 2.98E-03 2.38E-03 CONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP 1.46E-01 9.70E-02 CONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP 1.46E-01 9.72E-02 CONTROLLED 0%

NEIOK2720 ATLAS PIPELINE MIDCONTINENT WESTOK 3.77E-02 2.50E-02 CONTROLLED 0%

NEITX039674 HASTINGS WEST COMPRESSOR STATION 7.88E-02 5.24E-02 CONTROLLED 0%

NEITX039675 HASTINGS CENTRAL COMPRESSOR 7.88E-02 5.24E-02 CONTROLLED 0%

NEITX039676 HASTINGS SOUTH COMPRESSOR STATION 7.88E-02 5.24E-02 CONTROLLED 0%

NEITX039692 WEST ANKENMAN SALES POINT 8.16E-02 5.42E-02 CONTROLLED 0%

NEITX105012K TIPPETT PLANT 2.12E-02 1.41E-02 CONTROLLED 0%

NEITX161629 BUFFALO CENTRAL GATHERING 7.06E-02 4.69E-02 CONTROLLED 0%

NEITX161629 BUFFALO CENTRAL GATHERING 7.06E-02 4.69E-02 CONTROLLED 0%

NEITX167130 ALTA LOMA COMPRESSOR STATION 3.59E-03 2.39E-03 CONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT 1.94E-02 1.29E-02 CONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT 1.97E-02 1.62E-02 CONTROLLED 0%

NEITX239041N MAURBRO COMPRSR STN 1 8.45E-02 8.41E-02 CONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT 0.00E+00 0.00E+00 CONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT 0.00E+00 0.00E+00 CONTROLLED 0%

NEITX25150 HAYS COMPRESSOR STATION 4.80E-03 3.19E-03 CONTROLLED 0%

B-18
APPENDIX B

Summary of NEI Data for Small Glycol Dehydration Units by Facility – Oil and Natural Gas Production Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy)

Current Control 

Status

Required 

Emission 

Reduction

NEITX25152 MEADOWS COMPRESSOR SITE 1.81E-02 1.20E-02 CONTROLLED 0%

NEITX25152 MEADOWS COMPRESSOR SITE 7.23E-02 4.81E-02 CONTROLLED 0%

NEITX285067U NORTH WORD GAS PLANT 1.10E-02 1.10E-02 CONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT 2.06E-03 1.37E-03 CONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT 1.85E-02 1.23E-02 CONTROLLED 0%

NEITX42345 ARNOLD 2 1 CENTRAL PRODUCTION 

FACILITY

1.91E-01 1.27E-01 CONTROLLED 0%

NEITX461001M CRANE GAS PLANT 1.30E-01 8.64E-02 CONTROLLED 0%

NEITX461002K WILSHIRE PLANT 2.15E-02 1.83E-02 CONTROLLED 0%

NEITX461006C BENEDUM GAS PLANT 2.18E-01 1.45E-01 CONTROLLED 0%

NEITXRCI0100 SOUTH MAYES STATION 2.33E-02 2.00E-02 CONTROLLED 0%

NEITXRGJ0139 WILLOW SPRINGS PLANT 7.25E-02 7.16E-02 CONTROLLED 0%

NEITXRHG7260 SHORE ACRES COMPRESSOR 6.00E-04 5.00E-04 CONTROLLED 0%

NEITXRPE0106 YATES FIELD TRACT 75 PLANT 3.92E-03 2.61E-03 CONTROLLED 0%

B-19
APPENDIX C

Summary of NEI Data for Small Glycol Dehydration Units by Facility

Natural Gas Transmission and Storage Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy) Current Control Status

Required 

Emission 

Reduction

NEI32782 DUKE ENERGY FIELD SERVICES, LP 1.65E+01 3.56E+00 UNCONTROLLED 0%

NEI32782 DUKE ENERGY FIELD SERVICES, LP 1.20E+01 8.00E+00 UNCONTROLLED 0%

NEI7412 WAHA PLANT 1.09E+01 9.28E+00 UNCONTROLLED 0%

NEICO11678 QUESTAR GAS MANAGEMENT COMPANY 3.42E+00 3.42E+00 UNCONTROLLED 0%

NEICO11678 QUESTAR GAS MANAGEMENT COMPANY 6.42E+00 6.15E+00 UNCONTROLLED 0%

NEICO11678 QUESTAR GAS MANAGEMENT COMPANY 1.02E+01 9.71E+00 UNCONTROLLED 0%

NEIKS13235 ANADARKO GATHERING COMPANY 3.94E+00 2.30E+00 UNCONTROLLED 0%

NEIKS13245 ANADARKO GATHERING COMPANY 4.63E+00 2.72E+00 UNCONTROLLED 0%

NEIWV0050020 DANVILLE COMPRESSOR STATION 2.95E+01 2.58E+01 UNCONTROLLED 95%

NEIWV0390046 BONHAM COMPRESSOR STATION 2.58E+01 2.21E+01 UNCONTROLLED 95%

NEIWV0790046 HEIZER COMPRESSOR STATION 6.92E+00 4.92E+00 UNCONTROLLED 0%

NEIWV0990012 BEECH FORK COMPRESSOR STATION 2.87E+01 2.50E+01 UNCONTROLLED 95%

NEIWV1090017 BRADLEY COMPRESSOR STATION 3.04E+01 2.68E+01 UNCONTROLLED 95%

NEIWV20071 CRANBERRY PIPELINE CORPORATION 2.26E+01 1.92E+01 UNCONTROLLED 95%

NEIWV20071 CRANBERRY PIPELINE CORPORATION 2.15E+01 1.78E+01 UNCONTROLLED 95%

Group 2 NEI11382 MOSS BLUFF HUB PARTNERS 1.00E-03 1.00E-03 UNCONTROLLED 0%

(Dehydration units NEI11382 MOSS BLUFF HUB PARTNERS 7.84E-06 5.22E-06 UNCONTROLLED 0%

with uncontrolled NEI12421 STATION 581 4.00E-04 2.66E-04 UNCONTROLLED 0%

emissions less NEI12421 STATION 581 8.63E-05 5.74E-05 UNCONTROLLED 0%

than 1 tpy) NEI12805 MITCHELL PLANT 3.14E-03 2.09E-03 UNCONTROLLED 0%

NEI13136 L.A. PAN GAS STORAGE FCL. 5.10E-04 3.39E-04 UNCONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA 1.88E-03 1.25E-03 UNCONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA 1.88E-03 1.25E-03 UNCONTROLLED 0%

NEI2IA02-007 NATURAL GAS PIPELINE CO. OF AMERICA - 

STATION 204

5.49E-03 3.65E-03 UNCONTROLLED 0%

NEI2IA02-007 NATURAL GAS PIPELINE CO. OF AMERICA - 

STATION 204

3.92E-03 2.61E-03 UNCONTROLLED 0%

NEI2IA02-007 NATURAL GAS PIPELINE CO. OF AMERICA - 

STATION 204

2.43E-02 1.62E-02 UNCONTROLLED 0%

1 (Dehydration 

units with 

uncontrolled 

benzene emissions 

greater than 1 tpy)

C-1
APPENDIX C

Summary of NEI Data for Small Glycol Dehydration Units by Facility

Natural Gas Transmission and Storage Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy) Current Control Status

Required 

Emission 

Reduction

NEI2KY100052 COLUMBIA NATURAL RESOURCES 6.20E-01 4.13E-01 UNCONTROLLED 0%

NEI2KY100052 COLUMBIA NATURAL RESOURCES 6.12E-01 4.07E-01 UNCONTROLLED 0%

NEI2MS100040 CROSSTEX ACQUISITION MANAGEMENT 

LP HEI

9.10E-02 8.80E-02 UNCONTROLLED 0%

NEI2OK3163 ENOGEX GAS GATHERING LLC 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEI2TX4579 JACKS CREEK TANK BATTERY 7.31E-02 4.86E-02 UNCONTROLLED 0%

NEI2TX4579 JACKS CREEK TANK BATTERY 2.20E-04 1.46E-04 UNCONTROLLED 0%

NEI32782 DUKE ENERGY FIELD SERVICES, LP 5.43E+00 9.06E-01 UNCONTROLLED 0%

NEI32782 DUKE ENERGY FIELD SERVICES, LP 7.83E-04 5.21E-04 UNCONTROLLED 0%

NEI6482 KELSEY STATION 3.69E-04 2.45E-04 UNCONTROLLED 0%

NEI6794 STRATTON RIDGE STORAGE FACILITY 2.51E+00 2.51E+00 UNCONTROLLED 0%

NEI6794 STRATTON RIDGE STORAGE FACILITY 9.41E-05 6.26E-05 UNCONTROLLED 0%

NEI7119 PANOMA PLANT 1 3.11E-03 2.07E-03 UNCONTROLLED 0%

NEI7244 ENCINAL STATION 7.06E-02 4.69E-02 UNCONTROLLED 0%

NEI7244 ENCINAL STATION 3.14E-03 2.09E-03 UNCONTROLLED 0%

NEI7412 WAHA PLANT 3.45E-04 2.30E-04 UNCONTROLLED 0%

NEI7537 BUFFALO WALLOW 7.63E-01 6.41E-01 UNCONTROLLED 0%

NEI8351 BETHEL STORAGE COMPRESSOR STATION 7.84E-06 5.22E-06 UNCONTROLLED 0%

NEI8351 BETHEL STORAGE COMPRESSOR STATION 7.84E-06 5.22E-06 UNCONTROLLED 0%

NEI8351 BETHEL STORAGE COMPRESSOR STATION 4.71E-05 3.13E-05 UNCONTROLLED 0%

NEIIL137867A Panhandle Eastern Pipeline Co 2.15E+00 1.43E+00 UNCONTROLLED 0%

NEIKS12958 NORTHERN NATURAL GAS COMPANY 2.04E-02 1.36E-02 UNCONTROLLED 0%

NEIKS13235 ANADARKO GATHERING COMPANY 2.67E-01 1.77E-01 UNCONTROLLED 0%

NEILA1130126 AGL RESOURCES/JEFFERSON ISLAND 

STORAGE & HUB

7.84E-02 5.22E-02 UNCONTROLLED 0%

NEILA13384 ACADIAN GAS PIPELINE/GRAND BAYOU 

STORAGE FACILITY

4.38E-01 4.06E-01 CONTROLLED 0%

NEILA13384 ACADIAN GAS PIPELINE/GRAND BAYOU 

STORAGE FACILITY

3.92E-01 3.61E-01 CONTROLLED 0%

C-2
APPENDIX C

Summary of NEI Data for Small Glycol Dehydration Units by Facility

Natural Gas Transmission and Storage Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy) Current Control Status

Required 

Emission 

Reduction

NEIMI117N624 ANR PIPELINE COMPANY WINFIELD DEHY 

PLANT

1.03E-02 6.86E-03 UNCONTROLLED 0%

NEIMI117N624 ANR PIPELINE COMPANY WINFIELD DEHY 

PLANT

7.84E-05 5.22E-05 UNCONTROLLED 0%

NEIMI14228 OVERISEL COMPRESSOR STATION 3.22E-02 2.14E-02 UNCONTROLLED 0%

NEIMI14228 OVERISEL COMPRESSOR STATION 7.45E-04 4.96E-04 UNCONTROLLED 0%

NEINE15699 KMIGT Big Springs Station 7.84E-04 5.22E-04 UNKNOWN 0%

NEINM16513 Lindrith Compressor Station 1.81E-02 5.30E-05 UNCONTROLLED 0%

NEINM16705 Cedar Hill Compressor Station 3.81E+00 3.81E+00 UNCONTROLLED 0%

NEINY029R005 TENNECO GAS COMPRESSOR STATION 229 1.74E-01 1.42E-01 UNCONTROLLED 0%

NEINY9026000 INDEPENDENCE STATION 6.10E-03 6.10E-03 UNCONTROLLED 0%

NEINY9026000 INDEPENDENCE STATION 6.10E-03 6.10E-03 UNCONTROLLED 0%

NEINY9027400 BEECH HILL COMPRESSOR STATION 6.10E-03 6.10E-03 UNCONTROLLED 0%

NEINY9027400 BEECH HILL COMPRESSOR STATION 6.10E-03 6.10E-03 UNCONTROLLED 0%

NEIOK1056 ANADARKO GATHERING CO 3.17E-02 2.11E-02 UNCONTROLLED 0%

NEIOK1272 MIDSTREAM ENGRY SVC LLC 2.35E-03 1.56E-03 UNCONTROLLED 0%

NEIOK1272 MIDSTREAM ENGRY SVC LLC 1.60E+00 1.07E+00 UNCONTROLLED 0%

NEIOK1272 MIDSTREAM ENGRY SVC LLC 3.14E-03 2.09E-03 UNCONTROLLED 0%

NEIOK2371 DCP MIDSTREAM LP 8.52E-01 5.66E-01 UNCONTROLLED 0%

NEIOK2372 Panhandle Eastern Pipeline Co 1.44E+01 1.27E+01 UNCONTROLLED 95%

NEIOK2372 Panhandle Eastern Pipeline Co 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEIOK2374 DCP MIDSTREAM LP 4.03E-01 2.68E-01 UNCONTROLLED 0%

NEIOK401491548 ENOGEX GAS GATHERING LLC 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEITX065094I BURNETT MAIN COMPRESSOR 7.84E-04 5.22E-04 UNCONTROLLED 0%

NEITX161FI01 DEW GATHERING SYSTEM 2.05E-02 1.36E-02 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX 1.18E-04 7.82E-05 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX 3.77E-04 2.50E-04 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX 4.39E-04 2.92E-04 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX 1.41E-04 9.39E-05 UNCONTROLLED 0%

NEITXRSQ0095 ESPY COMPRESSOR STATION 6.43E-04 4.28E-04 UNCONTROLLED 0%

NEITXRSQ0095 ESPY COMPRESSOR STATION 5.79E-01 3.85E-01 UNCONTROLLED 0%

C-3
APPENDIX C

Summary of NEI Data for Small Glycol Dehydration Units by Facility

Natural Gas Transmission and Storage Source Category

Group NTI_SITE_ID FACILITY NAME

HAP 

Emissions 

(tpy)

BTEX 

Emissions 

(tpy) Current Control Status

Required 

Emission 

Reduction

NEIUT10253 Westwater Compressor Station 2.01E+00 1.96E+00 UNCONTROLLED 0%

NEIWV0395403900050 CARBON COMPRESSOR STATION 9.25E-04 6.15E-04 UNCONTROLLED 0%

NEIWV0395403900050 CARBON COMPRESSOR STATION 5.85E-02 3.89E-02 UNCONTROLLED 0%

NEIWV0990012 BEECH FORK COMPRESSOR STATION 5.16E-01 3.43E-01 UNCONTROLLED 0%

Group 3 NEI11118 EAST VILLAGE MILLS 2.93E-01 1.28E-01 CONTROLLED 0%

(Dehydration units NEI13099 BAMMEL GASFIELD 7.50E-03 7.50E-03 CONTROLLED 0%

with controlled NEI13099 BAMMEL GASFIELD 7.50E-03 7.50E-03 CONTROLLED 0%

benzene emissions NEI13099 BAMMEL GASFIELD 7.50E-03 7.50E-03 CONTROLLED 0%

less than 0.05 tpy) NEI13099 BAMMEL GASFIELD 2.10E-02 2.10E-02 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD 5.50E-03 5.40E-03 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD 5.20E-03 5.00E-03 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD 1.85E-02 1.78E-02 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD 1.87E-02 1.80E-02 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD 1.87E-02 1.80E-02 CONTROLLED 0%

NEI13136 L.A. PAN GAS STORAGE FCL. 4.25E-02 4.13E-02 CONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA 6.45E-03 4.29E-03 CONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA 6.45E-03 4.29E-03 CONTROLLED 0%

NEI2OK3163 ENOGEX GAS GATHERING LLC 8.99E-02 5.98E-02 CONTROLLED 0%

NEI2TX21310 TRI CITIES STA 2.83E-02 1.88E-02 CONTROLLED 0%

NEI2TX21310 TRI CITIES STA 2.83E-02 1.88E-02 CONTROLLED 0%

NEI2TX21310 TRI CITIES STA 2.83E-02 1.88E-02 CONTROLLED 0%

NEI7244 ENCINAL STATION 2.46E-01 1.63E-01 CONTROLLED 0%

NEI7431 NEW YORK STORAGE STATION 8.87E-02 6.94E-02 CONTROLLED 0%

NEI8351 BETHEL STORAGE COMPRESSOR STATION 1.52E-02 1.40E-02 CONTROLLED 0%

NEIKS13245 ANADARKO GATHERING COMPANY 8.62E-02 5.73E-02 CONTROLLED 0%

NEILA0010059 MARKET HUB PARTNERS LP/EGAN LA #1 

PROJECT

7.84E-02 5.22E-02 CONTROLLED 0%

NEITX157266K KATY HUB & STORAGE PLANT 2.00E-02 2.00E-02 CONTROLLED 0%

NEITX157266K KATY HUB & STORAGE PLANT 2.30E-03 1.53E-03 CONTROLLED 0%

NEITX161FI01 DEW GATHERING SYSTEM 2.49E-02 1.66E-02 CONTROLLED 0%

NEITX36562 BECKVILLE COMPRESSOR STATION 1.37E-01 9.13E-02 CONTROLLED 0%

C-4