# 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: July 28, 2011

SUBJECT: Oil and Natural Gas Production MACT and Natural Gas Transmission and

Storage MACT

- Glycol Dehydrators: Impacts of MACT Review Options

FROM: Heather P. Brown, P.E. , EC/R Inc.

TO: Bruce Moore , EPA/OAQPS/SPPD/ FIG

Greg Nizich, EPA/OAQPS/SPPD/ FIG

On June 17, 1999, the U.S. Environmental Protection Agency (EPA) promulgated 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. These standards reflect the maximum degree of emission reductions of hazardous air pollutants ( HAP ) achiev ed (after considering cost, energy requirements and nonair quality health and environmental impacts) and are commonly referred to as maximum achievable control technology ( MACT ) standards.

Under section 112(d)(6) of the Clean Air Act (CAA), th e EPA is required to review these technology

- based standards and to revise them “as necessary (taking into account developments in practices, processes, and control technologies)” no less frequently than every 8 years, under CAA section 112(d)(6). In condu cting this review, the EPA is not obliged to completely recalculate the prior MACT determination. NRDC v. EPA , 529 F.3d 1077, 1084 (D.C. Cir. 2008).

The purpose of this memorandum is to present the impacts of the MACT review options for glycol dehydrati on unit in the oil and natural gas production and the natural gas transmission and storage source categories.

GLYCOL DEHYDRATION UNIT PROCESS DESCRIPTION

Once natural gas has been separated from any liquid materials or products (e.g., crude oil, condens ate, or produced water), residual entrained water is removed from the natural gas by dehydration. Dehydration i s necessary because water vapor in the natural gas may form ice

- like structures, called hydrates, which can cause corrosion or plug equipment lin es. The most widely used natural gas dehydration processes are glycol dehydration and solid desiccant dehydration. Solid desiccant dehydration uses adsorption to remove water and is not a source of HAP emissions.

### 2

Glycol dehydration is an absorption proce ss in which a liquid absorbent, glycol, directly contacts the natural gas stream and absorbs any entrained water vapor in a contact tower or absorption column. The majority of glycol dehydration units use triethylene glycol (TEG) as the absorbent, but ethy lene glycol (EG) and diethylene glycol (DEG) are also used. The rich glycol, which has absorbed water vapor from the natural gas stream, leaves the bottom of the absorption column and is directed either to (1) a gas condensate glycol separator (GCG ) separa tor
, or flash tank

, and then a reboiler or (2) directly to a reboiler where the water is boiled off of the rich glycol. The regenerated glycol (lean glycol) is recirculated, by pump, into the absorption tower. The vapor generated in the reboiler is directe d to the reboiler vent

.

The reboiler vent is a source of HAP emissions. In the glycol contact tower, glycol not only absorbs water but also absorbs selected hydrocarbons, including benzene, toluene, ethyl benzene, xylenes (collectively referred to as BT EX), and n

- hexane. The hydrocarbons are boiled off along with the water in the reboiler and vented to the atmosphere or to a control device. The most commonly used control device is a condenser. Condensers not only reduce emissions, but also recover conden sable hydrocarbon vapors that can be recovered and sold. In addition, the dry

non

- condensable off

- gas from the condenser may be used as fuel or recycled into the production process or directed to a flare, incinerator, or other combustion device.

If prese nt, the GCG separator (flash tank) is also a potential source of HAP emissions. Some glycol dehydration units use flash tanks prior to the reboiler to separate entrained gases, primarily methane and ethane from the glycol. The flash tank off

- gases are typi cally recovered as fuel or recycled to the natural gas production header. However, the flash tank may also be vented directly to the atmosphere. Flash tanks typically enhance the reboiler condenser’s emission reduction efficiency by reducing the concentrat ion of non

- condensable gases present in the stream prior to being introduced into the condenser.

SUMMARY OF THE EXISTING MACT STANDARDS

There are two regulations impacting glycol dehydration units at major sources of HAP emissions: t he Oil and Natural G as Production NESHAP (subpart HH) and the Natural Gas Transmission and Storage NESHAP (subpart HHH). Under subpart HH, the standards apply to the glycol dehydration unit process vent , which is defined as the glycol dehydration unit reboiler vent and the ve nt from the gas

- condensate

- glycol (GCG) separator (i.e., flash tank), if present. The standards apply to glycol dehydration units with an actual annual average natural gas flowrate greater than or equal to 3 million standard cubic feet per day (MMscf/day) and actual average benzene emissions greater than or equal to 1 ton per year ( tpy )

. Each glycol dehydration unit process vent subject to the standards is required to be connected to a closed vent system to a single control device or a combination of contro l devices. The control device is required to reduce HAP emissions from the glycol dehydration unit process vent by 95 percent or reduce benzene emissions to a level less than 1 tpy. A combination of process modifications (e.g., reduction of the glycol reci rculation rate to its optimal level) and control devices is also allowed to achieve these levels of control.

The requirements under subpart HHH are the same as subpart HH, with the exception that the standards apply to glycol dehydration units with an ac tual annual average natural gas

### 3

flowrate greater than or equal to 10 MMscf/day and actual average benzene emissions greater than or equal to 1 tpy.

In the development of the MACT standards, the EPA created two subcategories of glycol dehydrators based on actual annual average natural gas flowrate and actual average benzene emissions. The first subcategory , described above, was glycol dehydration units with an actual annual average natural gas flowrate greater than or equal to 3 MMscf/day (for subpart HH) or 10 MMscf/day (for subpart HHH) and actual average benzene emissions greater than or equal to 1 tpy

. The second subcategory consist ed of glycol dehydration units that are below either of the se flowrate and emission thresholds. Standards were not establis hed for this second subcategory

, refer red to as “small dehydrators

. ” T he EPA, under the authority of section 112(d)(2) and (d)(3) is proposing to regulate these sources.

MACT STANDARDS FOR SMALL GLYCOL DEHYDRATION UNITS

S ection 112(d) of the CAA , requir es the EPA to establish standards to reflect the maximum degree of reduction in HAP emissions through application of MACT. The EPA is required to establish standards that are no less stringent than the level of control defined under section 112(d)(3), the MACT floor. Under section 112 (d)(3) of the CAA , the minimum baseline (the floor) at which standards may be set, for existing sources, is the “average emission limitation achieved by the best performing 12 percent of the existing sources

. ” The EPA looks at emission limitations achieved by each of the best performing 12 percent of existing sources, and averages those limitations. “Average” is interpreted by the Agency to mean a measure of central tendency such as the arithmetic mean, median, or mode or some o ther central tendency within the data. The following discussion details the means by which MACT standards were established for small glycol dehydration units in the Oil and Natural Gas Production source category and the Natural Gas Transmission and Storage source category.

Oil and Natural Gas Production Source Category

New emissions data concerning the small glycol dehydration unit emission points in the Oil and Natural Gas Production source category were not available; therefore, we evaluated the datase t collected from industry during the development of the original MACT standards (legacy docket A

- 94

- 04, item II

- B

- 01, disk 1). 1 

### We believe this dataset is representative of currently operating glycol dehydrators because it contains information for a varied group of sources ( i.e.

, units owned by different companies, located in different states, representing a range of gas compositions and emission controls) and that the processes have not changed significantly since the data were collected. In this dataset t here were 91 glycol dehydration units with throughput and emissions data identified that would be classified as small glycol dehydration units. Table 1 presents a summary of this data.

First it was evaluated whether the MACT floor should be established as a tpy limit. The approach is to rank sources by emissions from lowest to highest. Because the best performing 12 percent of the existing sources are considered to define the MACT floor, the presence of control devices is not considered. The MACT floor w ould be equal to the average emissions (controlled and uncontrolled) of the 11 sources (12 percent of 91, rounded up to the next whole number)

### 4

Table 1

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

Unit ID No. Legacy Docket

A

- 94

- 04, Docket ID No. Number

of Units * BTEX

Inlet Conc. (ppmv) BTEX Emissions (tpy) b † Through

put (MM scf /D ) BTEX

Emission Factor (lb/MMscf

- ppmv) Control Technique B 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 Condenser followed by combustion device; flash tank is vented
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 None C II

- D

- 19, pg 73 5 60 0.007 0.021 0.016 0.040 0.084 1.60 4.78E

- 03 Condenser then vapor recovery unit
D II

- D

- 19, pg 21 1 140 0.600 0 0 0 0. 600 3.50 6.71E

- 03 None E II

- D

- 10, pg 115 1 39 0 0.10 0 0 0.10 1.50 9.37E

- 03 None F II

- D

- 19, pg 41 1 308 0.40 0.30 0 0.20 0.90 1.04 1.54E

- 02 None G II

- D

- 19, pg 39 4 5 0.02 0 0 0 0.02 1.60 1.54E

- 02 None H II

- D

- 19, pg 79 3 1560 4.90 2.20 0.200 0.60 7.90 1.00 2.77E

- 02 None I II

- D

- 24, pg 42 1 40 0.64 0.90 1.461 2.011 5.02 17.50 3.93E

- 02 None J II

- D

- 19, pg 27 1 823 3.00 0.70 0.400 0.300 4.40 0.70 4.18E

- 02 None K II

- D

- 19, pg 43 1 1499 4.60 1.70 0.10 0.10 6.50 0.55 4.32E

- 02 None
L II

- D

- 13, pg 40 2 1400 1.70 6.10 0.60 9.30 17.70 1.60 4.33E

- 02 None M II

- D

- 23, pg 41 1 400 1.20 2.60 0 0 3.80 1.20 4.34E

- 02 None N II

- D

- 11, pg 53 1 340 5.10 1.20 0.30 0.90 7.50 2.20 5.49E

- 02 Condenser; flash tank overhead routed to inlet separator O II

- D

- 08, pg 19 2 348 0.99 1.47 0.15 2.10 4.71 1.30 5.71E

- 02 None P II

- D

- 19, pg 53 1 174 0.80 3.90 1.00 4.70 10.40 5.11 6.41E

- 02 None Q II

- D

- 02, pg 4 1 50 0 3.50 0 0 3.50 5.80 6.61E

- 02 None R II

- D

- 12, pg 36 6 150 0.10 0.10 0 0 0.2 0.10 7.31E

- 02 None S II

- D

- 23, pg 35 1 400 1.50 3.00 0 0 4.50 0.80 7.71E

- 02 None
T II

- D

- 19, pg 65 3 216 0.40 1.40 0.10 2.00 3.90 1.20 8.24E

- 02 None U II

- D

- 03, pg 6 30 316 0.50 2.30 0.20 1.80 4.80 1.00 8.32E

- 02 None V II

- D

- 19, pg 51 2 329 1.30 4.20 0.60 5.60 11.7 2.00 9.74E

- 02 None W II

- D

- 19, pg 63 3 102 0.30 0.50 0 0.40 1.20 0.65 9.92E

- 02 None

* 

### Data were submitted by each company for a “representative” glycol dehydration unit. If number of units that were represented by the data submitted was not provided, it was assumed that only one glycol dehydration unit was present. † 

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

### 5

Table 1

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

Unit ID No. Legacy Docket

A

- 94

- 04, Docket ID No. Number

of Units * BTEX

Inlet Conc. (ppmv) BTEX Emissions (tpy) b † Through

put (MM scf /D ) BTEX

Emission Factor (lb/MMscf

- ppmv) Control Technique B T E X Total X II

- D

- 03, pg 7 1 668 0.60 4.20 0.70 8.30 13.80 1. 10 1.03E

- 01 None
Y II

- D

- 10, pg 23 1 157 0.20 0.10 0.500 1.60 2.40 0.75 1.12E

- 01 None Z II

- D

- 13, pg 42 2 2560 0.70 2.20 0.20 2.30 5.40 0.10 1.16E

- 01 None AA II

- D

- 19, pg 75 3 320 1.3 2.6 0.30 2.7 6.9 1.00 1.18E

- 01 None BB II

- D

- 19, pg 49 2 198 0.7 2.4 0.20 2.0 5.3 1.21 1.21E

- 01 None CC II

- D

- 11, pg 27 2 920 10.5 18.0 5.50 25.3 59.3 2.70 1.31E

- 01 Flash tank overheads routed to compression
DD II

- D

- 19, pg 93 1 19 0.2 0.7 0.40 1.7 3.0 6.34 1.36E

- 01 None EE II

- D

- 23, pg 29 1 500 1 .2 1.9 0 1.5 4.6 0.32 1.58E

- 01 None FF II

- D

- 15, pg 57 1 32 0.2 1.8 0.20 0.3 2.5 2.30 1.86E

- 01 Condenser; flash tank recycled to process. GG II

- D

- 19, pg 91 3 39 0.2 1.0 0.10 0.6 1.9 1.34 2.00E

- 01 None HH II

- D

- 13, pg 18 1 410 0.70 0.10 0.4 0 0.30 1.50 0.09 2.23E

- 01 None
91 Total Number of Units Avg of top 12% ‡ 0.286 tpy 6.86E

- 03 lb BTEX/MMscf

- ppmv 11 § 12% of Total


### ‡ MACT floor of 0.286 tpy BTEX and 6.86x10 - 3 

### lb BTEX/MMscf

- ppmv calculated by averaging BTEX emissions a nd BTEX emission factor, respectively, from the top 11 facilities (which represent 12 percent of the total). § 

### Shaded cells represent facilities considered in the MACT floor. There are four glycol dehydration units represented by item II

- D

- 19, pg 39 and on ly one unit is included in the floor calculations.

### 6

with the lowest emissions. However, as shown in Table 1, the gas throughput and inlet gas composition is highly v ariable from one source to another

. As an example, the lowest BTEX emissions (0.004 tpy) are from a glycol dehydration unit w ith a natural gas throughput of 0.62 MMscf/day (Unit A). In contrast, the glycol dehydration unit with the lowest natural gas throughput of 0 .09 MMscf/day (Unit HH) has BTEX emissions of 1.5 tpy. Another example of this variability is shown by a comparison between Units F and H. The two sources have similar throughputs (1.04 MMscf/day vs. 1.00 MMscf/day, respectively) and both sources are

uncon trolled. However, the BTEX emissions differ by an order of magnitude (0.90 tpy for Unit F vs. 7.90 tpy for Unit H). This can be explained by the difference in inlet BTEX concentration. The inlet BTEX concentration for Unit F is 308 ppmv and 1,560 ppmv for Unit H. Due to this variability, the best performing units could not be identified by only considering emissions.

Therefore, in order to normalize the emission s to accurate ly identify the best performing sources, an emission factor was created in terms of pounds of BTEX per standard cubic feet per parts per million by volume (lb BTEX/ MM scf

- ppmv). This emission factor reflects the source’s emission level, but also takes into account its natural gas throughput and inlet natural gas BTEX concentration. The emission factors for each source are also presented in Table 1. Once the emission factors were developed, the sources were ranked from lowest emission factor to highest. This ranking is presented in Table 1, with the top 11 glycol dehydration units being h ighlighted. The MACT floor was determined to be 6.86x10 - 3 

### lb BTEX/ MM scf

- ppmv.

Natural Gas Tr ansmission and Storage Source Ca tegory

Similar to the Oil and Natural Gas Production source category, new emissions data were not available for this analysis. Th erefore, the emissions dataset collected from the industry during the development of the original MACT standards was evaluated (legacy docket A

- 94

- 04, items IV

- G

- 24, 26, 27, 30, and 31)

. 2

, 3

, 4

, 5

, 6 

### Again, w e believe this dataset is representative of currentl y operating glycol dehydrators because it contains information for a varied group of sources ( i.e. , units owned by different companies, located in different states, representing a range of gas compositions and emission controls) and that the processes have not changed significantly since the data were collected. These data are summarized in Table 2. There were 16 sources for which throughput and emissions data were available that would be classified as small glycol dehydration units. Since the number of un its was less than 30, the MACT floor was based on the top five performing units.

Using the rationale used for the Oil and Natural Gas Production source category, the same emission factor concept was applied. As shown in Table 2, the MACT floor was deter mined to be the average emission factor for the best five performing sources, 4.01x10 - 3 

### lb BTEX/scf

- ppmv.

AFFECTED SOURCES

To identify the existing small glycol dehydration units that would be subject to the MACT standard, we used the 2005 National Emis sions Inventory (NEI) dataset. 7 

### Within this dataset, 368 facilities in the oil and natural gas production sector with one or more glycol dehydration units were identified, 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

### 7

Table 2. MACT Floor analysis for Glycol Dehydration Units in the Natural Gas Transmission and Storage Source Category

Unit ID No. Docket ID Number of Units BTEX

Inlet Conc. (ppmv) BTEX Emissions (tpy) a

Throughput (MMSCF/D) BTEX Emission

Factor (lb/MMscf

- ppmv) Control

status (y or n) B T E X Total A IV

- G

- 30, pg 12 1 155 0.111 0.154 0.004 0.120 0.388 20.0 6.86E

- 04 N

B IV

- G

- 30, pg 10 1 155 0.189 0.263 0.007 0.204 0.663 30.0 7.81E

- 04 N

C IV

- G

- 30, pg 8 1 155 0.234 0.326 0.008 0.253 0.822 35.0 8.30E

- 04 N

D IV

- G

- 27, pg 8 1 20 0.993 1.972 0 0 2.965 120.0 6.77E

- 03 N

E I V

- G

- 27, pg 10 1 20 0.816 1.588 0 0 2.404 60.0 1.10E

- 02 N

F IV

- G

- 31, pg 19 1 24 0.525 1.594 0 3.659 5.777 50.0 2.64E

- 02 N

G IV

- G

- 26, No. 1 1 29.98 0.389 0.731 0.667 0.970 2.757 12.5 4.03E

- 02 N

H IV

- G

- 27, pg 26 1 39.96 0.185 0.324 0.490 0.6 83 1.682 5.3 4.32E

- 02 N

I IV

- G

- 24, pg 9 1 24 0.240 0.454 0.066 0.332 1.092 5.7 4.37E

- 02 N

J IV

- G

- 26, No. 2 1 40 0.275 0.491 0.391 1.648 2.805 7.0 5.49E

- 02 N

K IV

- G

- 26, No. 3 1 49.98 1.182 2.235 0.974 1.182 5.573 7.0 8.73E

- 02 N

L IV

- G

- 2 6, No. 4 1 27 0.576 2.098 2.310 2.193 7.176 15.0 9.71E

- 02 N

M IV

- G

- 26, No. 5 1 26 0.569 2.055 2.245 2.116 6.985 15.0 9.81E

- 02 N

N IV

- G

- 26, No. 6 1 29.94 0.294 0.625 0.609 0.751 2.278 4.0 1.04E

- 01 N

O IV

- G

- 26, No. 7 1 29.98 0.295 0.532 0 .441 0.525 1.794 3.0 1.09E

- 01 N

P IV

- G

- 31, pg 27 1 34 0.321 0.773 0 0.180 1.275 0.9 2.36E

- 01 N

16 Total Number of Units Avg of top 12% 4.01E

- 03

5 12% of Total 1.45 tpy 

### Shaded cells represent facilities considered in the MACT floor.

a 

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

### 8

source category that has a natural gas throughput less than 3 MMscf/day or benzene emissions less than 1 tpy. The following glycol dehydration units in the production source category we re considered to be small glycol dehydration units :

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

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

 G lycol dehydration units with controll ed 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 n atural gas throughput less than 3 MMscf/day. However, t he 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 t hese assumptions 495 small glycol dehydration units were identified

. 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. 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. As shown in Table 1, the MACT floor of 6.86x10

- 3 lb BTEX/MMscf

- ppmv is equivalent to 0.286 tpy BTEX. A ny glycol dehydration unit identified a s a small glycol dehydration unit with controlled or uncontrolled BTEX emissions greater than 0.286 tpy would be required to reduce their emissions to a level below 0.286 tpy BTEX. Attachment 1 presents the facilities and glycol dehydration units that would be affected by the MACT standard for small glycol dehydration units.

As shown in Attachment 1, 115 glycol dehydration units would be required to reduce their emissions to meet the MACT floor of 6.86x10

- 3 lb BTEX/MMscf

- ppmv (or 0.286 tpy)

. Of these 115 units, 85 glycol dehydration units required 95 percent emission reduction or le ss 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 conde nser (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 cate gory. 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 th roughputs less than

### 9

10 MMscf/day

. A total of 110 glycol dehydration units were identified wit h : (1) uncontrolled benzene emissions less than 1 tpy; (2) uncontrolled benzene emission greater than 1 tpy, or (3) controlled benzene emissions less than 0. 0 5 tpy. Attachment 2 presents these small glycol dehydration units identified for the transmission and storage source category. As shown in Table 2, the MACT floor of 4.01x10 - 3 

### lb BTEX/MMscf

- ppmv for the transmission and storage source category is equivalent to 1.45 tpy of BTEX. Of the 110 small glycol dehydration units identified

, 1 9 would be required to install controls to achieve the MACT floor (see Attachment 2) ; 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, it was 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. * These control technologies are not required by the standards, but were assumed for the purposes of evaluating the cost impacts related the small glycol dehydrat ion unit MACT standards.

As previously discussed, the e mission 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 deh ydration 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 wit h 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) , it was 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%, the facility would install a VRU and a condens er (assumed to achieve a combined emission reduction of 99.75%). If the facility was already controlled, it was assumed that a vapo r recovery unit (assumed to achieve 95% control) would be installed.

Cost estimates for condensers were developed for the 1998 proposed subpart HH and HHH and are documented in the Background Information Document (BID). 8 

### The original cost estimates wer e based on 1993 cost data. Therefore, these estimates were revised to reflect 2008 prices using the Chemical Engineering 9 

### cost index for equipment costs and information from the Bureau of Labor Statistics for labor rates

. 10



### For units identified for whic h it was assumed that condensers would be installed , it was assumed that 10 percent of the units would already be equipped with a flash tank and the

__________________________ * 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.

### 10

remaining 90 percent would be required to install a flash tank in addition to the condenser

. Table 3 presen ts 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 4 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 5 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) ar e presented in Table 6. These costs were based on a study performed on the installation of an environmental VRU. 11 

### Emissions 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 7 presents the annual costs for VRUs.

The nationwide impacts of the small glycol dehydration units MACT standards were estimated by multiplying the number of affected units by the costs. The nationwide impacts are presented in Tables 8 and 9 for the oil and natural gas production and transmission and storage source categories, respectively. Control technologies were assigned to the facilities in Attachments 1 and 2, according to the level of control required to meet the MACT floor.

SECONDARY ENVIRONMENTAL IMPACTS

Although the intent of the MACT standar ds 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 emis sions, 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 im pacts associated with the application of this type of control are the decreased VOC emissions resulting from capture and control of HAP emissions. No adverse secondary air impacts would be expected from either of these control technologies.

Water and Sol id 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 r eprocessing with the hydrocarbon condensate or, if separated, combined with produced water for disposal by reinjection. 8 

### No water impacts would be associated with the operation of a VRU.

### 11

Table 3. Total Capital Investment for Small Glycol Dehydration Units that Install a

Condenser plus Flash Tank ( Dehy

- A)

Equipme nt Description Size Factor Reference Jul

- 93 Cost 2008

Cost † Condenser Condenser,

piping to control device All 8 $6,800 ‡ $9,92 1

Condensate storage vessel Fixed

- roof

tank 50 gal 2.72 (Vtank) + 1,960 

### 12 $2,210 $3,224

Flash tank Low pres sure

separator 125 psig 8 $1,750 $2,553

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

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

Total capital investment for a new unit (TCIN) § PEC + EM $11,840 $17,270

Total capital investment for an existing unit (TCIE) ** 1.15(TCIN) $13,620 $19,860

Minor discrepancies may be due to rounding.

† 

### Costs escalated from July 1993 dollars to 2008 dollars using the ratio of Chemical Engineering cost indices (Reference 9 ). July 1993 C ost I ndex = 394.4 ; 200 8 Cost Index = 575.4

. ‡ 

### Direct and indirect costs are included in the condenser cost.
§ 

### Procedures followed from OAQPS Control Cost Manual for calculating PEC and TCI ( Reference 8 ).

** 

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

### 12

Table 4. Total Capital Investment for Small Glycol Dehydration Units that Install a Condens er ( Dehy

- B )

Equipment Description Size Factor Reference Jul

- 93 Cost 2008

Cost * Condenser Condenser,

piping to control device All 8 $6,800 † $9,92 1

Condensate storage vessel Fixed

- roof

tank 50 gal 2.72 (Vtank) + 1,960 

### 12 $2,210 $3,224

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

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

Total capital investment for a new unit (TCIN) § PEC + EM $9,910 $14,460

To tal capital investment for an existing unit (TCIE) § 1.15(TCIN) $11,400 $16,630

Minor discrepancies may be due to rounding.

* 

### Costs escalated from July 1993 dollars to 2008 dollars using the ratio of Chemical Engineering cost indices (Reference 9 ). July 1993 C ost I ndex = 394.4 ; 2008 Cost Index = 575.4

. † 

### Direct and indirect costs are included in the condenser cost. ‡ 

### Procedures followed from OAQPS Control Cost Manual for calculating PEC and TCI ( Reference 8 ). § 

### Total capital investment for an existing unit accounts for a ret rofit factor of 1.15.

### 13

Table 5 . Total Annual Costs for Small Glycol Dehydration Units that Install Condensers ( Dehy

- A and Dehy

- B ) *

Cost Component Fac tor Dehy

- A Dehy

- B Direct Annual Costs (DAC) †

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

Supervising labor 0.15 x Operating labor x management labor rate § 937 594

Operating materials None required 0 0

Maintenance Labor 130 hours/yr x $technical labor rate ‡ 3,960 3,960 Material 0.50 x Maintenance labor § 1,980 1,980

Utilities None required

Indi rect Annual Costs (IAC) †

Overhead 0.60 x Total labor + Maintenance $5,314 $5,109 Administrative 0.02 x TCIE ** 397 333 Property tax 0.01 x TCIE ** 199 166 Insurance 0.01 x TCIE ** 199 166 Capital recovery †† 0.1098 x TCIE ** 2,181 1,826

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

Minor discrepancies may be due to rounding.

* 

### 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)

. † 

### Procedures followed from OAQPS Control Cost Manual for calc ulating PEC and TCI ( Reference 8 ). ‡ Technical Labor Rate = $30.46/hr (Reference 10 ) § Management Labor Rate = $48.04/hr (Reference 10 )

** TCIE from Table 3 for Dehy

- A and Table 4 for Dehy

- B †† 

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

### 14

Table 6. Total C apital Investment for Small Glycol Dehydration Units that Install a Vapor Recovery Unit

Equipment Description Size Factor Reference 2002 Cost 2008 Cost * VRU Vapor

Recovery Unit All 11 $69,510 $101,102

Includes transportati on and delivery

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

Labor,and Materials for Installation Costs (L&M) 11 $38,448 $55,923

Total capital investment for a new unit ( TCIN) § PEC + L&M $107,960 $157,020

Total capital investment for an existing unit (TCIE) ‡ 1.15(TCIN) $124,150 $180,570

Minor discrepancies may be due to rounding.

* 

### Costs escalated from 2002 dollars to 2008 dollars using the ratio of Chemical Engineering cost indices (Referen ce 9 ). 2002 C ost I ndex = 39 5.6; 2008 Cost Index = 575.4

. † 

### Procedures followed from OAQPS Control Cost Manual for calculating PEC and TCI ( Reference 8 ). ‡ 

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

### 15

Table 7. Total Annual Costs for Small Glycol Dehydration Units that Install a Vapor Recovery Unit

Cost Component Factor Dehy

- A Direct Annual Costs (DAC) *

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

Supervising labor 0.15 x Operating labor x management labor rate ‡ 937

O perating materials None required 0

Maintenance Labor 130 hours/yr x $technical labor rate ‡ 3,960 Material 0.50 x Maintenance labor § 1,980

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

dollars 13 

### 3,687

Indirect Annual Costs (IAC) †

Overhead 0.60 x Total labor + Maintenance $5,314 Administrative 0.02 x TCIE § 3,611 Property tax 0.01 x TCIE * * 

### 1,806 Insurance 0.01 x TCIE * * 

### 1,806 Capital recovery ** 0.1098 x TCIE * * 

### 19,827

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

Minor di screpancies may be due to rounding.

* 

### Procedures followed from OAQPS Control Cost Manual for calculating PEC and TCI ( Reference 8 ). † Technical Labor Rate = $30.46/hr (Reference 10 ) ‡ Management Labor Rate = $48.04/hr (Reference 10 ) § TCIE from Table 3 for Dehy

- A and Table 4 for Dehy

- B

** 

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

### 16 Table 8 . Nationwide Cost Impacts for the Oil and Natural Gas Production Source Category

Control Technology * Total Capital Investment Per Existing Unit ($) † Number

of Affected Units Nationwide

Total Capital Investment ($) Total Annual

Cost per Existing Unit ($/yr) ‡ Nationwide Total

Annual Cost ($/yr) Baseline

HAP Emissions (tpy) HAP

Emission Reduction (tpy) HAP Cost

Effectiveness ($/ton) Install Condenser + Flash Tank 19,860 77 1,519,290 19,100 1,461,150 157 149 $9,8 23

Install Condenser 16,630 9 141,355 18,100 153,850 17.4 17 $9,309

VRU + Condenser + Flash Tank 200,430 23 4,509,675 66,000 1,485,000 335 334 $4,441

VRU + Condenser 197,200 3 493,000 65,000 162,500 37.2 37 $4,374 VRU Only 180,570 5 902,850 46,900 234 ,500 12.2 12 $20,309

Total 115 $7,566,170 $3,497,000 559 548 $6,377 

### Minor discrepancies may be due to rounding.

* Assu med 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. † See Tables 3, 4, and 6. ‡ See Tables 5 and 7.

### 17 Table 9. Nationwide Cost Impacts for the Oil and Natural Gas Production Source Category

Control Technology * Total Capital Investment Per Existing Unit ($) † Number

of Affected Unit Nationwide

Total Capital Investment ($) Total

Annual Cost per Existing Unit ($/yr) ‡ Nationwide

Total Annual Cost ($/yr) Baseline

HAP Emissions (tpy) HAP

Emission Reduction (tpy) HAP Cost

Effectiveness ($/ton) Install Condenser + Flash Tank $19,860 17 $339,606 $19,100 $326,610 231 219 $1,491

Install Condenser $16,630 2 $31,597 $18,100 $34,390 25.6 24 $1,413

Total 19 $371,203 $361,000 256 243 $1,483 

### Minor discrepancies may be due to rounding.

* Assumed that 10 percent of units are equipped with a flash tank (supported by MACT Floor dataset). In order for the condense r to operate properly, a flash tank must be installed. Costs reflect the addition of a flash t ank where none is present. † See Tables 3, 4, and 6. ‡ See Tables 5 and 7.

### 18

There is no solid w aste generated from the control of HAP emissions using condenser s 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 impact s 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 dehydr ation 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 pr oducts, 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.

REFERENCES

1

. Floppy disks containing a summary of the information obtained from the completed air emissions questionnaires. Legacy Docket Number A

- 94

- 04, Item II

- B

- 001.

2

. D. Uran, Williston Basin Interstate Pipeline Company, to G. Ni zich, EPA:WCPG. Transmittal of completed response to the EPA’s Section 114 survey questionnaire. September 14, 1998. Legacy Docket Number A

- 94

- 04, Item IV

- G

- 24.

3

. V. Ammirato, Columbia Gas Transmission Corporation, to B. Jordan, EPA:ESD. Transmittal of completed response to the EPA’s section 114 survey questionnaire. October 14, 1998. Legacy Docket Number A

- 94

- 04, Item IV

- G

- 26.

4

. T. Bach, KN Energy, Inc., to B. Jordan, EPA:ESD. Transmittal of completed response to the EPA’s section 114 survey que stionnaire. October 14, 1998. Legacy Docket Number A

- 94

- 04, Item IV

- G

- 27.

5

. L. Sugano, Questar Pipeline Company, to G. Nizich, EPA:WCPG. Transmittal of completed response to the EPA’s section 114 survey questionnaire. October 7, 1998. Legacy Docket Num ber A

- 94

- 04, Item IV

- G

- 30.

6

. W. Ebarb, NorAm Gas Transmission Company, to G. Nizich, EPA:WCPG. Transmittal of completed response to the EPA’s section 114 survey questionnaire. October 7, 1998. Legacy Docket Number A

- 94

- 04, Item IV

- G

- 31.

7

. 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.

### 19

8

. 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.

9

. Chemical Engineering. http://www.che.com. August 2004. Economic Indi cators.

10

. “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 ma

jor 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).

11

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

12

. 

### OAQPS Control Cost Manual: Fourth Edition (EPA 450/3

- 90

- 006, January 1990). U.S. Environmental Protection Agency. Research Triangle Park, NC.

13

. Fernandez, R, U.S. Environmental Protection Agency, Natural Gas STAR Program, et al. "Cost Effective Methane Emissions Reductions for S mall and Midsize Natural Gas Producers" Journal of Petroleum Technology. June 2005

## ATTACHMENT 1

Summary of NEI Data for Small Glycol Dehydration Units by Facility

Oil and Natural Gas Production Source Category

### Attac hment 1, Page 1 ATTACHMENT 1 Summary of NEI Data for Small Glycol Dehydration Units by Facility

– Oil and Natural Gas Production Source Category

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor † Group 1 (Dehydration units with uncontrolled benzene emissions greater than 1 tpy)

NEI11215 GORDON GAS PROCESSING
PLANT NEI11215000019000030000031 3.82E+00 7.54E+00 UNCONTROLLED 95%

NEI11296 WHARTON GAS PLANT NEI11296000008000008000009 3.83E+00 4.05E+00 UNCONTROLLED 95%

NEI12150 VIDOR PRODUCTION FACILITY NEI12150000006000006000006 5.83E+00 5.92E+00 UNCONTROLLED 99.75%

NEI12443 EXPRO ENGINEERING NEI12443000002000010000010 5.97E+00 6.01E+00 UNCONTROLLED 99.75%

NEI12443 EXPRO ENGINEERING NEI12443000008000004000004 3.56E+00 3.59E+00 UNCONTROLLED 95%

NEI12474 J L DAVIS PEARSALL PLANT NEI12474000001000001000015 3.01E+00 3.27E+00 UNCONTROLLED 95%

NEI12494 FAIN GAS PLANT NEI12494000014000039000037 2.10E+01 3.24E+01 UNCONTROLLED 99.75%

NEI13135 NINE MILE PT CMPSR STATION NEI13135000015000002000003 3.67E+00 3.76E+00 UNCONTROLLED 95%

NEI2CO0145 ENCANA OIL & GAS (USA) INC

- PARK CANY NEI2CO014501002001 1.33E+01 1.33E+01 UNCONTROLLED 99.75%

NEI2CO045365 WILLIAMS PROD RMT CORP

- PARACHUTE NEI2CO04536501010010 4.71E+00 4.71E+00 UNCONTROLLED 95%

NEI2CO045366 ENCANA OIL & GAS (USA) INC

- GASAWAY NEI2CO04536601003003 1.48E+01 1.48E+01 UNCONTROLLED 99.75%

NEI2CO045366 ENCANA OIL & GAS (USA) INC

- GASAWAY NEI2CO04536601004004 9.82E+00 1.05E+01 UNCONTROLLED 99.75%

* Dehy ID number was created from the NEI by combining the NEI Site ID with the facility process code, emission unit code and emissi on point code. † Emission reduction required to meet the MACT floor was determined by comparing the dehydration unit’s BTEX emissi ons to 0.286 tpy (the equivalent to MACT floor of 6.86x10 - 3 lb BTEX/MMscf

- ppmv). If the dehydration unit emissions were greater than the MACT floor, control was required regardless of whether the un it was already equipped with a control device. It was ass umed that the types of controls included a condenser (assumed to achieve 95 percent control), a vapor recovery unit plus a co ndenser (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. It should be noted that if the emission reduction required to achieve a level emissions below the MACT floor was less than 95%, it was assumed for cost purposes that the facility w ould install a condenser. Likewise if the required reduction was greater than 95% but less than 99.75%, the facility would i nstall a VRU and a condenser.

### Attac hment 1, Page 2

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI2CO045368 ENCANA OIL & GAS (USA) INC

- PUMBA NEI2CO04536801007007 1.40E+01 1.51E+01 UNCONTROLLED 99.75%

NEI2CO045370 ENCANA GATHERING

- MAMM
CRK CONDITIONI NEI2CO04537001010010 8.97E+00 8.97E+00 UNCONTROLLED 99.75%

NEI2CO045370 ENCANA GATHERING

- MAMM
CRK CONDITIONI NEI2CO04537001017017 2.85E+00 6.46E+00 UNCONTROLLED 95%

NEI2TX14311 HUCKABAY GAS PLANT NEI2TX14311000001000013000013 5.27E+00 5.75E+00 UNCONTROLLED 95%

NEI2TX416 E LAKE CREEK COMPRESSOR NEI2TX416000003000003000003 3.96E+00 4.14E+00 UNCONTROLLED 95%

NEI6476 BRECKENRIDGE BOOSTER
STATION NEI6476000018000018000018 1.16E+01 1.23E+01 UNCONTROLLED 99.75%

NEI6574 GIDDINGS PLANT NEI6574000005000005000005 3.94E+00 3.94E+00 UNCONTROLLED 95%

NEI6597 CONGER GATHERING FACILITY NEI6597000011000011000011 5.35E+00 1.01E+01 UNCONTROLLED 95%

NEI6956 CLAM LAKE COMPR STA 1 NEI6956000005000005000005 2.87E+00 3.17E+00 UNCONTROLLED 95%

NEI7417 SHACKELFORD PLANT NEI7417000014000014000015 3.58E+00 3.71E+00 UNCONTROLLED 95%

NEI7511 MILLERS BEND COMP STN NEI7511000003000011000006 1.57E+01 1.59E+01 UNCONTROLLED 99.75%

NEI7554 DARK CANYON COMPR STAT NEI7554000001000011000008 1.11E+01 1.13E+01 UNCONTROLLED 99.75%

NEI7597 GRAHAM COMPRESSOR
STATION NEI7597000004000013000004 7.80E+00 7.92E+00 UNCONTROLLED 99.75%

NEI8001 VAN GASOLINE PLANT 19 NEI8001000018000018000018 6.23E+00 6.53E+00 UNCONTROLLED 99.75%

NEICO0090045 MIDSTREAM ENERGY

- SPELUNKER CS NEICO009004501003003 4.28E+01 4.33E+01 UNCONTROLLED 99.75%

NEICO0450077 CANYON GAS RESOURCES

- RIFLE C S NEICO045007701006006 5.34E+00 6.64E+00 UNCONTROLLED 95%

NEICO0450077 CANYON GAS RESOURCES

- RIFLE C S NEICO045007701007007 6.57E+00 6.57E+00 UNCONTROLLED 99.75%

NEICO0450077 CANYON GAS RESOURCES

- RIFLE C S NEICO045007701010010 6.37E+00 7.07E+00 UNCONTROLLED 99.75%

NEICO0450187 ENCANA

- TRAIL RIDGE STA & 1

- 23 NEICO045018701004004 7.01E+00 7.01E+00 UNCONTROLLED 99.75%

### Attac hment 1, Page 3

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEICO0450187 ENCANA

- TRAIL RIDGE STA & 1

- 23 NEICO045018701007007 1.78E+01 1.78E+01 UNCONTROLLED 99.75%

NEICO0450228 WILLIAMS PRODUCTION RMT
CO

- ROAN CLIFF NEICO045022801010010 3.55E+00 3.55E+00 UNCONTROLLED 95%

NEICO1230057 KERR

- MCGEE FT LUPTON
COMPRESSOR STATION NEICO123005701010010 5.03E+01 5.54E+01 UNCONTROLLED 99.75%

NEIOK1709 ATLAS PIPELINE MIDCONTINENT
WESTOK LLC NEIOK17095549068436843 2.19E+00 2.45E+00 UNCONTROLLED 95%

NEIOK2002 ONEOK FIELD SVC NEIOK20024292220552055 1.77E+01 1.89E+01 UNCONTROLLED 99.75%

NEITX115009S WELCH CO2 PLANT NEITX115009S000017000037000032 1.17E+01 1.57E+01 UNCONTROLLED 99.75%

NEITXRHM0010 FAIRWAY GAS PLT NEITXRHM0010000021000022000021 2.60E+00 2.60E+00 UNCONTROLLED 95%

NEITXRYB0046 GIBSON COMPRESSOR STATION NEITXRYB0046000004000005000005 1.47E+01 1.51E+01 UNCONTROLLED 99.75% Group 2(Dehydration units with uncontrolled emissions less than 1 tpy)

NEI11127 TAFT COMPRESSOR STATION NEI11127000013000013000005 2.05E

- 01 2.27E

- 01 UNCONTROLLED 0%

NEI11187 SAND HILLS PLANT NEI11187000026000026000026 9.39E

- 04 1.41E

- 03 UNCONTROLLED 0%

NEI11191 WQPUEBLO PLANT NEI11191000011000010000012 8.61E

- 04 1.29E

- 03 UNCONTROLLED 0%

NEI11207 MCMULLEN COMPRESSOR
STATION NEI11207000001000014000014 3.55E

- 01 7.11E

- 01 UNCONTROLLED 95%

NEI11211 CONROE COMPRESSOR
STATION NEI11211000001000065000047 4.08E

- 03 6.13E

- 03 UNCONTROLLED 0%

NEI11215 GORDON GAS PROCESSING
PLANT NEI11215000011000038000043 2.33E+00 5.42E+00 UNCONTROLLED 95%

NEI11215 GORDON GAS PROCESSING
PLANT NEI11215000020000029000030 1.58E

- 03 2.38E

- 03 UNCONTROLLED 0%

NEI11239 PORT NECHES FIELD NEI11239000001000001000001 1.25E

- 04 1.88E

- 04 UNCONTROLLED 0%

NEI11239 PORT NECHES FIELD NEI11239000006000007000006 2.40E

- 01 2.40E

- 01 UNCONTROLLED 0%

NEI11296 WHARTON GAS PLANT NEI11296000007000007000008 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEI11476 MAGNET WITHERS STATION NEI11476000017000017000017 3.03E

- 01 3.03E

- 01 UNCONTROLLED 95%

### Attac hment 1, Page 4

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI11594 MAGNET WITHERS COMP
STATION NEI11594000001000001000001 9.18E

- 04 1.38E

- 03 UNCONTROLLED 0%

NEI11594 MAGNET WITHERS COMP
STATION NEI11594000011000011000008 7.62E

- 02 8.63E

- 02 UNCONTROLLED 0%

NEI11771 NORTH POINT BOLIVAR FIELD NEI11771000017000017000016 2.61E

- 05 3.92E

- 05 UNCONTROLLED 0%

NEI11924 MORGAN BLUFF FIELD NEI11924000061000061000060 1.83E

- 04 2.75E

- 04 UNCONTROLLED 0%

NEI11926 PORTILLA GAS PLANT NEI11926000018000020000020 4.59E

- 04 6.90E

- 04 UNCONTROLLED 0%

NEI11929 OYSTER BAYOU NEI11929000012000020000014 4.17E

- 04 6.28E

- 04 UNCONTROLLED 0%

NEI12032 NORTHWEST OZONA PLANT NEI12032000009000009000009 1.39E

- 02 9.21E

- 02 UNCONTROLLED 0%

NEI12032 NORTHWEST OZONA PLANT NEI12032000015000015000015 4.96E

- 04 7.45E

- 04 UNCONTROLLED 0%

NEI12032 NORTHWEST OZONA PLANT NEI12032000016000016000016 1.15E

- 02 1.27E

- 02 UNCONTROLLED 0%

NEI12047 WASKOM GAS PLANT NEI12047000010000144000121 2.44E

- 03 3.67E

- 03 UNCONTROLLED 0%

NEI12059 KARON PLANT NEI12059000001000017000007 3.91E

- 04 5.88E

- 04 UNCONTROLLED 0%

NEI12059 KARON PLANT NEI12059000002000016000012 5.90E

- 01 8.87E

- 01 UNCONTROLLED 95%

NEI12065 MANSFIELD COMPRESSOR STN NEI12065000013000013000012 7.30E

- 01 7.92E

- 01 UNCONTROLLED 95%

NEI12079 PROSPECT COMPRESSOR STN NEI12079000007000003000003 1.65E

- 01 1.84E

- 01 UNCONTROLLED 0%

NEI12088 FIG RIDGE CENTRAL NEI12088000010000007000004 6.00E

- 04 1.30E

- 03 UNCONTROLLED 0%

NEI12150 VIDOR PRODUCTION FACILITY NEI12150000004000004000004 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000001000053000050 1.68E

- 03 2.53E

- 03 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000002000052000048 5.00E

- 04 7.00E

- 04 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000003000051000048 1.00E

- 03 1.30E

- 03 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000004000050000049 1.78E

- 03 2.68E

- 03 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000029000025000025 3.03E

- 04 4.55E

- 04 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000030000024000048 6.26E

- 05 9.41E

- 05 UNCONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000061000005000006 1.36E

- 04 2.04E

- 04 UNCONTROLLED 0%

### Attac hment 1, Page 5

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI12380 SHERMAN GAS PLANT NEI12380000013000014000014 2.62E

- 03 3.94E

- 03 UNCONTROLLED 0%

NEI12425 POINT BARROW FACILITY NEI12425000002000017000015 2.97E

- 04 4.47E

- 04 UNCONTROLLED 0%

NEI12443 EXPRO ENGINEERING NEI12443000001000011000011 8.87E

- 05 1.33E

- 04 UNCONTROLLED 0%

NEI12443 EXPRO ENGINEERING NEI12443000006000006000006 5.22E

- 05 7.84E

- 05 UNCONTROLLED 0%

NEI12470 MIDWAY LANE GAS PLANT NEI12470000009000009000010 1.21E

- 03 1.82E

- 03 UNCONTROLLED 0%

NEI12470 MIDWAY LANE GAS PLANT NEI12470000013000014000013 8.14E

- 04 1.22E

- 03 UNCONTROLLED 0%

NEI12474 J L DAVIS PEARSALL PLANT NEI12474000020000020000019 2.45E

- 04 3.69E

- 04 UNCONTROLLED 0%

NEI12487 PEGASUS GAS PLANT NEI12487000007000060000052 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEI12487 PEGASUS GAS PLANT NEI12487000008000059000053 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEI12494 FAIN GAS PLANT NEI12494000028000023000020 2.26E

- 03 3.40E

- 03 UNCONTROLLED 0%

NEI12504 KEYSTONE PLANT NEI12504000052000054000008 3.39E

- 02 5.10E

- 02 UNCONTROLLED 0%

NEI13085 LAKE CREEK PLANT NEI13085000033000051000010 4.17E

- 04 6.28E

- 04 UNCONTROLLED 0%

NEI13271 ALAZAN COMPRESSOR STATION NEI13271000003000034000032 4.22E

- 04 6.35E

- 04 UNCONTROLLED 0%

NEI2CO045365 WILLIAMS PROD RMT CORP

- PARACHUTE NEI2CO04536501028028 1.89E

- 01 1.89E

- 01 UNCONTROLLED 0%

NEI2CO045367 ENCANA OIL & GAS

- HUNTER
MESA NEI2CO04536701004004 1.06E+00 1.06E+00 UNCONTROLLED 95%

NEI2CO045367 ENCANA OIL & GAS

- HUNTER
MESA NEI2CO04536701005005 1.06E+00 1.06E+00 UNCONTROLLED 95%

NEI2CO045367 ENCANA OIL & GAS

- HUNTER
MESA NEI2CO04536701007007 5.02E

- 01 5.02E

- 01 UNCONTROLLED 95%

NEI2CO045368 ENCANA OIL & GAS (USA) INC

- PUMBA NEI2CO04536801002002 1.62E+00 1.62E+00 UNCONTROLLED 95%

NEI2CO045370 ENCANA GATHERING

- MAMM
CRK CONDITIONI NEI2CO04537001002002 5.02E

- 01 5.02E

- 01 UNCONTROLLED 95%

NEI2CO0552 KERR

- MCGEE

- PLATTEVILLE CS NEI2CO055201004001 2.16E+00 2.16E+00 UNCONTROLLED 95%

### Attac hment 1, Page 6

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI2LA109024 ANADARKO E & P/CL & F NO 1
PF NEI2LA109024050505 7.24E

- 01 9.37E

- 01 UNCONTROLLED 95%

NEI2LA109024 ANADARKO E & P/CL & F NO 1
PF NEI2LA109024464646 9.32E

- 01 1.25E+00 UNCONTROLLED 95%

NEI2MIB9139 MERIT ENERGY CO.

- BLAIR 36
CPF NEI2MIB9139PR0001EU0002SV0001 1.08E+00 1.63E+00 UNCONTROLLED 95%

NEI2MIB9162 MERIT ENERGY CO.

- MAYFIELD
19 CPF NEI2MIB9162PR0001EU0002SV0001 4.10E

- 02 6.15E

- 02 UNCONTROLLED 0%

NEI2MIN6793 DTE GAS & OIL

- CHESTER 16 NEI2MIN6793PR0005EU0007FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN6939 DTE GAS & OIL

- OLD VANDY
NORTH NEI2MIN6939PR0003EU0005FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN6946 DTE GAS & OIL

- OLD VANDY
SOUTH NEI2MIN6946PR0001EU0009FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN6999 KCS RESOURCES INC. MAYFIELD
28 NEI2MIN6999PR0002EU0002SV0001 6.02E

- 01 9.04E

- 01 UNCONTROLLED 95%

NEI2MIN7084 DTE GAS AND OIL COMPANY

- BAGLEY 16 NEI2MIN7084PR0002EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN7086 DTE GAS AND OIL COMPANY

- WARNER 8 NEI2MIN7086PR0002EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN7087 DTE GAS AND OIL COMPANY

- WARNER 27 NEI2MIN7087PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN7088 DTE GAS & OIL COMPANY

- CUSTER 15/20 NEI2MIN7088PR0001EU0004FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN7089 DTE GAS AND OIL COMPANY

- JORDAN 12 NEI2MIN7089PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN7090 DTE GAS AND OIL COMPANY

- JORDAN 9 NEI2MIN7090PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN7091 DTE GAS & OIL COMPANY

- ECHO 26 NEI2MIN7091PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2MIN7093 DTE GAS AND OIL COMPANY

- KEARNEY 9 NEI2MIN7093PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

### Attac hment 1, Page 7

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI2MIN7094 DTE GAS & OIL COMPANY

- CUSTER 33 CPF NEI2MIN7094PR0002EU0007FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEI2TX03310 HANOVER REINECKE SITE NEI2TX03310000021000021000021 1.42E

- 01 2.13E

- 01 UNCONTROLLED 0%

NEI2TX039141 MANVEL FIELD CENTRAL
COMPRESSOR STATION NEI2TX039141000005000005000004 4.54E

- 04 6.82E

- 04 UNCONTROLLED 0%

NEI2TX039141 MANVEL FIELD CENTRAL
COMPRESSOR STATION NEI2TX039141000006000006000006 2.88E+00 3.24E+00 UNCONTROLLED 95%

NEI2TX0711 ANAHUAC COMPRESSOR
STATION NEI2TX0711000071000073000096 5.17E

- 01 7.78E

- 01 UNCONTROLLED 95%

NEI2TX07195 JACKSON HEIRS #1
PRODUCTION FACILITY NEI2TX07195000002000002000002 2.99E

- 01 3.48E

- 01 UNCONTROLLED 95%

NEI2TX101 GALVESTON ISLAND GATH
STATION NEI2TX101000008000008000005 4.17E

- 04 6.28E

- 04 UNCONTROLLED 0%

NEI2TX101 GALVESTON ISLAND GATH
STATION NEI2TX101000020000004000018 6.67E

- 01 3.59E+00 UNCONTROLLED 95%

NEI2TX101 GALVESTON ISLAND GATH
STATION NEI2TX101000021000009000019 4.46E

- 01 2.50E+00 UNCONTROLLED 95%

NEI2TX128 G.C.W.A. #1 PRODUCTION
FACILITY NEI2TX128000002000002000002 8.57E

- 02 8.57E

- 02 UNCONTROLLED 0%

NEI2TX1355 HANNA NASH FACILITY NEI2TX1355000004000003000002 1.12E+00 1.12E+00 UNCONTROLLED 95%

NEI2TX14311 HUCKABAY GAS PLANT NEI2TX14311000013000001000001 1.88E

- 03 2.82E

- 03 UNCONTROLLED 0%

NEI2TX1546 JOSEY RANCH 2, 4, 5
PRODUCTION FACILITY NEI2TX1546000002000002000002 2.66E

- 04 4.00E

- 04 UNCONTROLLED 0%

NEI2TX1546 JOSEY RANCH 2, 4, 5
PRODUCTION FACILITY NEI2TX1546000003000003000003 3.73E

- 02 3.73E

- 02 UNCONTROLLED 0%

NEI2TX1619 TEAGUE GAS PLANT NEI2TX1619000042000012000013 2.46E

- 03 3.70E

- 03 UNCONTROLLED 0%

NEI2TX211 CINCO LTD NO 1 FACILITY NEI2TX211000007000007000007 1.49E+00 1.65E+00 UNCONTROLLED 95%

NEI2TX21136 GOAD

- HEMPHILL COMPLEX NEI2TX21136000004000003000003 9.39E

- 04 1.41E

- 03 UNCONTROLLED 0%

NEI2TX21136 GOAD

- HEMPHILL COMPLEX NEI2TX21136000030000026000010 6.44E

- 01 9.68E

- 01 UNCONTROLLED 95%

### Attac hment 1, Page 8

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI2TX245668 HAYES KEITH #1 PRODUCTION
FACILITY NEI2TX245668000001000001000001 2.34E+00 2.41E+00 UNCONTROLLED 95%

NEI2TX245668 HAYES KEITH #1 PRODUCTION
FACILITY NEI2TX245668000009000009000009 1.20E

- 04 1.80E

- 04 UNCONTROLLED 0%

NEI2TX245668 HAYES KEITH #1 PRODUCTION
FACILITY NEI2TX245668000010000010000010 3.49E

- 01 5.25E

- 01 UNCONTROLLED 95%

NEI2TX2613 ARMSTRONG COMPRESSOR
STATION NEI2TX2613000005000009000006 1.22E

- 01 1.43E

- 01 UNCONTROLLED 0%

NEI2TX2615 CALANDRIA COMP STATION NEI2TX2615000003000003000004 3.44E

- 04 5.18E

- 04 UNCONTROLLED 0%

NEI2TX2615 CALANDRIA COMP STATION NEI2TX2615000008000008000008 1.48E+00 1.48E+00 UNCONTROLLED 95%

NEI2TX39132 LAKE PASTURE LP LEASE NEI2TX39132000023000009000009 6.36E+00 6.99E+00 UNCONTROLLED 99.75%

NEI2TX39132 LAKE PASTURE LP LEASE NEI2TX39132000025000007000007 6.18E+00 6.38E+00 UNCONTROLLED 99.75%

NEI2TX39132 LAKE PASTURE LP LEASE NEI2TX39132000028000004000004 1.04E

- 03 1.57E

- 03 UNCONTROLLED 0%

NEI2TX39132 LAKE PASTURE LP LEASE NEI2TX39132000030000002000002 1.04E

- 03 1.57E

- 03 UNCONTROLLED 0%

NEI2TX39139 TOM O'CONNER COMPRESSOR
STATION NEI2TX39139000007000001000001 6.26E

- 04 9.41E

- 04 UNCONTROLLED 0%

NEI2TX39140 FANNIE HEARD LEASE NEI2TX39140000006000005000004 6.26E

- 04 9.41E

- 04 UNCONTROLLED 0%

NEI2TX39140 FANNIE HEARD LEASE NEI2TX39140000007000004000004 2.87E

- 02 4.31E

- 02 UNCONTROLLED 0%

NEI2TX39520 BOA GAS TREATING PLANT NEI2TX39520000002000002000002 6.89E

- 03 1.04E

- 02 UNCONTROLLED 0%

NEI2TX39913 SALLIE ODOM STATION NEI2TX39913000005000005000005 4.54E

- 04 6.82E

- 04 UNCONTROLLED 0%

NEI2TX39913 SALLIE ODOM STATION NEI2TX39913000006000006000006 1.39E

- 01 1.39E

- 01 UNCONTROLLED 0%

NEI2TX40138 BUSBY CMPRSSR SAT NEI2TX40138000005000005000005 1.79E+00 1.80E+00 UNCONTROLLED 95%

NEI2TX416 E LAKE CREEK COMPRESSOR NEI2TX416000008000008000008 1.98E

- 04 2.98E

- 04 UNCONTROLLED 0%

NEI2TX42343 PERRY COMP COMMON POINT NEI2TX42343000006000003000003 3.03E

- 02 4.55E

- 02 UNCONTROLLED 0%

NEI2TX42343 PERRY COMP COMMON POINT NEI2TX42343000007000002000002 1.03E

- 01 1.03E

- 01 UNCONTROLLED 0%

NEI2TX42343 PERRY COMP COMMON POINT NEI2TX42343000015000014000014 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

### Attac hment 1, Page 9

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI2TX42343 PERRY COMP COMMON POINT NEI2TX42343000016000015000014 3.03E

- 02 4.55E

- 02 UNCONTROLLED 0%

NEI2TX4311 CONGER SALES FACILITY NEI2TX4311000018000018000017 1.36E

- 03 2.04E

- 03 UNCONTROLLED 0%

NEI2TX4311 CONGER SALES FACILITY NEI2TX4311000022000021000001 1.48E

- 01 1.77E

- 01 UNCONTROLLED 0%

NEI2TX669 BULLER LOCKE PRODUCTION
FACILITY NEI2TX669000011000011000011 5.66E

- 01 5.66E

- 01 UNCONTROLLED 95%

NEI2TX670 GUBERT NO. 1 PRODUCTION
FACILITY NEI2TX670000001000001000001 1.46E

- 04 2.20E

- 04 UNCONTROLLED 0%

NEI41887 PUCKETT COMPRESSOR
STATION NEI41887000004000014000014 1.05E

- 03 1.58E

- 03 UNCONTROLLED 0%

NEI42031 Bluebell Gas Plant NEI420311170414950191 9.73E

- 01 2.78E+00 UNCONTROLLED 95%

NEI6439 LONGVIEW GAS PLANT NEI6439000006000006000006 1.38E

- 03 2.07E

- 03 UNCONTROLLED 0%

NEI6439 LONGVIEW GAS PLANT NEI6439000042000041000042 1.08E

- 03 1.62E

- 03 UNCONTROLLED 0%

NEI6442 TRINIDAD GAS PLT NEI6442000023000024000024 5.31E

- 02 7.99E

- 02 UNCONTROLLED 0%

NEI6448 GIBTOWN COMPRESSOR STATN NEI6448000010000010000010 5.80E

- 01 6.58E

- 01 UNCONTROLLED 95%

NEI6449 W RANCH COMP STA VANDERB NEI6449000070000069000070 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEI6453 EXXON MOBIL SARITA COMPRE NEI6453000002000033000030 9.23E

- 04 1.39E

- 03 UNCONTROLLED 0%

NEI6453 EXXON MOBIL SARITA COMPRE NEI6453000024000015000023 1.15E

- 03 1.73E

- 03 UNCONTROLLED 0%

NEI6461 SALE RANCH GAS PLANT NEI6461000004000016000017 2.77E

- 02 6.27E

- 02 UNCONTROLLED 0%

NEI6461 SALE RANCH GAS PLANT NEI6461000006000014000013 1.22E

- 03 1.84E

- 03 UNCONTROLLED 0%

NEI6476 BRECKENRIDGE BOOSTER
STATION NEI6476000013000013000013 4.59E

- 04 6.90E

- 04 UNCONTROLLED 0%

NEI6483 KATY GAS PLANT NEI6483000084000070000051 1.50E

- 03 2.26E

- 03 UNCONTROLLED 0%

NEI6492 JAMESON GAS PLANT NEI6492000011000043000026 6.15E

- 04 9.26E

- 04 UNCONTROLLED 0%

NEI6509 CANADIAN PLANT NEI6509000017000017000016 1.10E

- 03 1.65E

- 03 UNCONTROLLED 0%

NEI6512 PAWNEE GAS PLANT NEI6512000010000010000010 2.53E

- 03 3.80E

- 03 UNCONTROLLED 0%

NEI6512 PAWNEE GAS PLANT NEI6512000027000028000026 1.84E

- 03 2.77E

- 03 UNCONTROLLED 0%

### Attac hment 1, Page 10

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI6523 SONORA GAS PLANT NO 2 NEI6523000007000007000007 1.18E

- 01 1.88E

- 01 UNCONTROLLED 0%

NEI6597 CONGER GATHERING FACILITY NEI6597000013000013000013 6.15E

- 04 9.26E

- 04 UNCONTROLLED 0%

NEI6602 WILLARD CO2 SEPARATION
PLANT NEI6602000021000006000006 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEI6603 CARGRAY PLANT NEI6603000025000025000024 1.25E

- 03 1.88E

- 03 UNCONTROLLED 0%

NEI6603 CARGRAY PLANT NEI6603000027000027000026 2.61E

- 01 3.92E

- 01 UNCONTROLLED 0%

NEI6752 BARTON CHAPEL PLANT NEI6752000014000015000015 2.10E+00 2.39E+00 UNCONTROLLED 95%

NEI6752 BARTON CHAPEL PLANT NEI6752000016000017000024 1.67E

- 04 2.51E

- 04 UNCONTROLLED 0%

NEI6752 BARTON CHAPEL PLANT NEI6752000017000018000025 1.67E

- 04 2.51E

- 04 UNCONTROLLED 0%

NEI6948 HUMBLE COMMON STORAGE NEI6948000006000003000003 6.12E

- 01 9.29E

- 01 UNCONTROLLED 95%

NEI6948 HUMBLE COMMON STORAGE NEI6948000007000002000002 4.17E

- 05 6.28E

- 05 UNCONTROLLED 0%

NEI6956 CLAM LAKE COMPR STA 1 NEI6956000004000004000003 2.61E

- 04 3.92E

- 04 UNCONTROLLED 0%

NEI6957 NELEH GAS PLANT NEI6957000001000001000001 9.31E

- 02 9.31E

- 02 UNCONTROLLED 0%

NEI6957 NELEH GAS PLANT NEI6957000008000007000008 3.08E

- 04 4.63E

- 04 UNCONTROLLED 0%

NEI6964 IRION PLANT NEI6964000004000004000004 4.33E

- 04 6.51E

- 04 UNCONTROLLED 0%

NEI6964 IRION PLANT NEI6964000005000005000005 2.50E

- 02 2.50E

- 02 UNCONTROLLED 0%

NEI6965 CHERRYHOMES CMPRSSR STN NEI6965000009000009000010 2.63E+00 2.78E+00 UNCONTROLLED 95%

NEI7311 DECATUR COMPRESSOR
STATION NEI7311000008000008000008 1.32E+00 1.38E+00 UNCONTROLLED 95%

NEI7380 HAMLIN GAS PLANT NEI7380000009000016000016 4.07E

- 02 6.12E

- 02 UNCONTROLLED 0%

NEI7410 SPRINGTOWN GAS PLANT NEI7410000083000021000023 1.60E

- 03 2.41E

- 03 UNCONTROLLED 0%

NEI7410 SPRINGTOWN GAS PLANT NEI7410000084000020000024 1.60E

- 03 2.41E

- 03 UNCONTROLLED 0%

NEI7417 SHACKELFORD PLANT NEI7417000009000009000010 6.21E

- 04 9.33E

- 04 UNCONTROLLED 0%

NEI7421 VIBORES COMPRESSOR
STATION NEI7421000036000029000036 2.35E

- 04 3.53E

- 04 UNCONTROLLED 0%

### Attac hment 1, Page 11

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI7421 VIBORES COMPRESSOR
STATION NEI7421000041000030000037 6.30E

- 02 9.48E

- 02 UNCONTROLLED 0%

NEI7426 LULING GAS PLANT NEI7426000019000019000017 3.06E

- 02 4.60E

- 02 UNCONTROLLED 0%

NEI7428 SCHAFER FACILITY NEI7428000028000026000028 8.87E

- 04 1.33E

- 03 UNCONTROLLED 0%

NEI7428 SCHAFER FACILITY NEI7428000029000027000027 8.24E

- 02 8.24E

- 02 UNCONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT NEI7436000037000002000002 3.70E

- 04 5.57E

- 04 UNCONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT NEI7436000039000047000045 6.15E

- 04 9.26E

- 04 UNCONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT NEI7436000040000048000046 6.15E

- 04 9.26E

- 04 UNCONTROLLED 0%

NEI7449 BRAZORIA NATURAL GAS
BOOSTER NEI7449000026000023000013 5.06E

- 04 7.61E

- 04 UNCONTROLLED 0%

NEI7449 BRAZORIA NATURAL GAS
BOOSTER NEI7449000029000026000027 1.88E

- 04 2.82E

- 04 UNCONTROLLED 0%

NEI7454 BRANNON COMPRESSOR NEI7454000002000008000008 7.96E

- 01 8.46E

- 01 UNCONTROLLED 95%

NEI7493 NONA MILLS C & W NEI7493000026000009000008 7.44E

- 01 7.44E

- 01 UNCONTROLLED 95%

NEI7499 PERRIN COMPRESSOR STATION NEI7499000011000011000009 3.64E

- 01 4.17E

- 01 UNCONTROLLED 95%

NEI7554 DARK CANYON COMPR STAT NEI7554000006000006000007 1.62E

- 04 2.43E

- 04 UNCONTROLLED 0%

NEI7578 CLEAR LAKE GAS PLANT NEI7578000066000074000094 1.21E+00 1.35E+00 UNCONTROLLED 95%

NEI7599 LIQUID SEPARATION PLANT (MILSP) NEI7599000002000011000009 2.09E

- 03 3.14E

- 03 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) NEI7599000003000010000010 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) NEI7599000004000009000011 1.41E

- 02 2.12E

- 02 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) NEI7599000008000005000005 5.77E

- 02 8.68E

- 02 UNCONTROLLED 0%

NEI7599 LIQUID SEPARATION PLANT (MILSP) NEI7599000010000003000003 5.83E

- 02 8.77E

- 02 UNCONTROLLED 0%

NEI7751 SNEED PLANT NEI7751000032000033000031 3.91E

- 02 5.89E

- 02 UNCONTROLLED 0%

### Attac hment 1, Page 12

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI7785 OYSTER LAKE FACILITY NEI7785000001000001000001 3.17E

- 01 3.17E

- 01 UNCONTROLLED 95%

NEI7785 OYSTER LAKE FACILITY NEI7785000005000005000005 3.17E

- 01 3.17E

- 01 UNCONTROLLED 95%

NEI7785 OYSTER LAKE FACILITY NEI7785000008000008000008 9.40E

- 01 9.40E

- 01 UNCONTROLLED 95%

NEI7787 TRAWICK CTRL TREATING STN NEI7787000034000025000006 4.54E

- 04 6.82E

- 04 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN NEI7787000035000026000008 4.54E

- 04 6.82E

- 04 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN NEI7787000036000027000010 4.54E

- 04 6.82E

- 04 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN NEI7787000040000032000002 1.70E

- 01 2.55E

- 01 UNCONTROLLED 0%

NEI7787 TRAWICK CTRL TREATING STN NEI7787000041000033000002 1.70E

- 01 2.55E

- 01 UNCONTROLLED 0%

NEI7839 TRAWICK WEST STATION NEI7839000007000007000004 3.34E

- 04 5.02E

- 04 UNCONTROLLED 0%

NEI7839 TRAWICK WEST STATION NEI7839000011000011000009 4.52E

- 02 6.79E

- 02 UNCONTROLLED 0%

NEI7844 GULF COAST FRACTIONATORS NEI7844000024000017000017 4.08E

- 01 4.53E

- 01 UNCONTROLLED 95%

NEI7978 EAST VEALMOOR GAS PLANT NEI7978000013000060000078 3.60E

- 01 4.00E

- 01 UNCONTROLLED 95%

NEI7990 EAST TEXAS GAS PLANT NEI7990000066000041000041 4.47E

- 03 6.72E

- 03 UNCONTROLLED 0%

NEI7992 BIG LAKE PLANT NEI7992000004000004000004 6.38E

- 02 6.38E

- 02 UNCONTROLLED 0%

NEI7992 BIG LAKE PLANT NEI7992000022000022000021 3.08E

- 04 4.63E

- 04 UNCONTROLLED 0%

NEI7992 BIG LAKE PLANT NEI7992000023000023000022 3.08E

- 04 4.63E

- 04 UNCONTROLLED 0%

NEI7998 SONORA GAS PLANT NEI7998000014000027000026 1.04E

- 03 1.57E

- 03 UNCONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000006000043000065 1.36E

- 02 2.05E

- 02 UNCONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000040000029000086 9.81E

- 04 1.47E

- 03 UNCONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000045000034000061 2.16E

- 03 3.26E

- 03 UNCONTROLLED 0%

NEI8017 NONA MILLS TRACT 185 NEI8017000018000003000003 1.69E+00 1.69E+00 UNCONTROLLED 95%

NEI8019 WIZARD WELLS CMPRSR STN NEI8019000007000007000001 9.45E

- 01 1.76E+00 UNCONTROLLED 95%

NEI8145 EAST CHICO COMPRESSOR
STATION NEI8145000009000010000010 6.15E

- 04 9.26E

- 04 UNCONTROLLED 0%

### Attac hment 1, Page 13

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI8145 EAST CHICO COMPRESSOR
STATION NEI8145000010000011000011 1.20E+00 1.24E+00 UNCONTROLLED 95%

NEICO0186 CALPINE NATURAL GAS
COMPANY

- MAMM CREEK NEICO018601007007 1.46E

- 01 1.46E

- 01 UNCONTROLLED 0%

NEICO0186 CALPINE NATURAL GAS
COMPANY

- MAMM CREEK NEICO018601008008 9.60E

- 02 9.60E

- 02 UNCONTROLLED 0%

NEICO0450077 CANYON GAS RESOURCES

- RIFLE C S NEICO045007701014014 2.66E+00 2.66E+00 UNCONTROLLED 95%

NEICO1030036 ENCANA OIL & GAS (USA) INC

DRAGON TRAIL NEICO103003601016016 8.35E

- 03 1.26E

- 02 UNCONTROLLED 0%

NEICO1230057 KERR

- MCGEE FT LUPTON
COMPRESSOR STATION NEICO123005701019019 1.33E

- 01 1.33E

- 01 UNCONTROLLED 0%

NEICO1230277 DUKE ENERGY FIELD SERVICES

- ENTERPRISE NEICO123027701068068 1.94E+00 1.94E+00 UNCONTROLLED 95%

NEILA00702000047 LINDER OIL CO/WILLIAMS
JEANERETTE L&S FACILITY NEILA00702000047111111 5.74E

- 01 8.63E

- 01 UNCONTROLLED 95%

NEILA0123 GULFPORT ENERGY CORP/W
COTE BLANCHE BAY DEHY NEILA0123515151 5.22E

- 02 7.84E

- 02 UNCONTROLLED 0%

NEILA01504000046 HUNT PETROLEUM CORP/SLIGO
FIELD CENTRAL FACILITY NEILA01504000046030303 1.04E

- 01 1.57E

- 01 UNCONTROLLED 0%

NEILA04512600052 APACHE CORP/BAYOU PIGEON
FIELD CENTRAL FACILITY NEILA04512600052060606 5.22E

- 02 7.84E

- 02 UNCONTROLLED 0%

NEILA04512600110 LINDER OIL CO/KYLE PETERMAN
MANAGEMENT CORP
PRODUCTION FACILITY NEILA04512600110131313 5.22E

- 02 7.84E

- 02 UNCONTROLLED 0%

NEILA04712800116 SOUTHERN BAY OPERATING LLC/SCHWING 10 PROD FAC

- FROG LAKE FIELD NEILA04712800116111111 2.09E

- 01 3.14E

- 01 UNCONTROLLED 0%

NEILA0750034 XPLOR ENERGY OPERATING CO/MAIN PASS BOCLK 35
CENTRAL FACILITY NEILA0750034171717 1.04E

- 01 1.57E

- 01 UNCONTROLLED 0%

### Attac hment 1, Page 14

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEILA07522400241 APACHE CORP/SOUTHEAST
PASS COMMON FACILITY #2 NEILA07522400241050505 1.04E

- 01 1.57E

- 01 UNCONTROLLED 0%

NEILA09325600076 HENRY PRODUCTION COMPANY/MILES TIMBER S22 D
#1 PROD FAC

- LOWER
VACHERIE FIELD NEILA09325600076030303 4.17E

- 01 6.28E

- 01 UNCONTROLLED 95%

NEILA09926200028 CHAPARRAL ENERGY INC/WILBERTS & SONS #1
PRODUCTION FACILITY NEILA09926200028010101 1.04E

- 01 1.57E

- 01 UNCONTROLLED 0%

NEILA09926200079 GOODRICH PETROLEUM CO LLC/PLUMB BOB FIELD CENTRAL
FACILITY NEILA09926200079040404 1.56E

- 01 2.35E

- 01 UNCONTROLLED 0%

NEILA13712 HILCORP ENERGY CO/S PASS 24
FACILITY #2 NEILA13712111111 5.22E

- 02 7.84E

- 02 UNCONTROLLED 0%

NEIMI001N6860 SAVOY ENERGY LP NEIMI001N6860PR0001EU0001FUG001 2.41E

- 02 3.61E

- 02 UNCONTROLLED 0%

NEIMI001N6860 SAVOY ENERGY LP NEIMI001N6860PR0001EU0003FUG001 2.41E

- 02 3.61E

- 02 UNCONTROLLED 0%

NEIMI001N7470 PETROLEUM DEVELOPMENT
INC NEIMI001N7470PR0006EU0011SV0005 3.60E

- 03 5.40E

- 03 UNCONTROLLED 0%

NEIMI001N7470 PETROLEUM DEVELOPMENT
INC NEIMI001N7470PR0007EU0012SV0006 3.60E

- 03 5.40E

- 03 UNCONTROLLED 0%

NEIMI007N624 HRF EXPLORATION AND
PRODUCTION INC NEIMI007N624PR0006EU0012SV0009 1.80E

- 03 2.70E

- 03 UNCONTROLLED 0%

NEIMI007N7453 QUICKSILVER RESOURCES

- BRADY BUNCH/LITTLE RASCALS NEIMI007N7453PR0003EU0003FUG001 5.22E

- 04 7.82E

- 04 UNCONTROLLED 0%

NEIMI007N7462 QUICKSILVER RESOURCES INC.

- BLUE HERRON/JACK SPRATT NEIMI007N7462PR0002EU0002FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI007N7472 QUICKSILVER RESOURCES

- CARBON BLACK ROHMAN
EMPIRE NEIMI007N7472PR0002EU0002FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI0096050 DTE GAS AND OIL COMPANY

- HAWK LAKE NEIMI0096050PR0001EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

### Attac hment 1, Page 15

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIMI0096055 DTE GAS AND OIL COMPANY

- JORDAN 35 NEIMI0096055PR0002EU0006FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI009N7455 QUICKSILVER RESOURCES INC

- ALL STATE STAR NEIMI009N7455PR0003EU0004FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI009N7457 QUICKSILVER RESOURCES INC.

- MANCELONA 8 NEIMI009N7457PR0005EU0005FUG001 8.87E

- 04 1.33E

- 03 UNCONTROLLED 0%

NEIMI055B915 MERIT ENERGY CO.

- GRANT 29 NEIMI055B915PR0001EU0003SV0002 1.08E

- 01 1.63E

- 01 UNCONTROLLED 0%

NEIMI055N6501 FEDERATED OIL & GAS
PROPERTIES NEIMI055N6501PR0002EU0005SV0003 6.02E

- 01 9.04E

- 01 UNCONTROLLED 95%

NEIMI055N7037 MERIT ENERGY L P ST GRANT 1

- 16 NEIMI055N7037PR0001EU0002FUG001 3.13E

- 02 4.70E

- 02 UNCONTROLLED 0%

NEIMI057N5570 NEW HAVEN COMPRESSOR
STATION NEIMI057N5570PR0005EU0009SV0005 2.11E

- 01 3.16E

- 01 UNCONTROLLED 0%

NEIMI079B756 KCS RESOURCES, INC. GOOSE
CREEK GSF NEIMI079B756PR0001EU0012SV0011 6.02E

- 01 9.04E

- 01 UNCONTROLLED 95%

NEIMI079N2455 QUICKSILVER RESOURCES INC.

- KALKASKA 1

- 21 CPF NEIMI079N2455PR0001EU0013FUG001 4.82E

- 01 7.23E

- 01 UNCONTROLLED 95%

NEIMI079N7092 DTE GAS & OIL COMPANY

- CLEARWATER 2 NEIMI079N7092PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI079N7409 QUICKSILVER RESOURCES INC.

- PDC BOOSTER NEIMI079N7409PR0002EU0002FUG001 2.38E

- 01 3.57E

- 01 UNCONTROLLED 0%

NEIMI107N632 CATO GLENWOOD FACILITY NEIMI107N632PR0022EU0044SV0037 9.11E

- 02 1.37E

- 01 UNCONTROLLED 0%

NEIMI1196155 DOMINION MIDWEST ENERGY,
WEST ALBERT 11 PROD. FAC. NEIMI1196155PR0013EU0008FUG001 2.61E

- 05 3.91E

- 05 UNCONTROLLED 0%

NEIMI1196192 MUSKEGON DEVELOPMENT,
MITCHEL LAKE II NEIMI1196192PR0001EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1196193 MUSKEGON DEVELOPMENT,
BIG WOLF LAKE NEIMI1196193PR0001EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI119N7252 HRF EXPLORATION &
PRODUCTION NEIMI119N7252PR0004EU0006SV0003 3.60E

- 03 5.40E

- 03 UNCONTROLLED 0%

### Attac hment 1, Page 16

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIMI119N7454 QUICKSILVER RESOURCES INC

- CATTLE ANTRIM NEIMI119N7454PR0002EU0002FUG001 3.39E

- 04 5.09E

- 04 UNCONTROLLED 0%

NEIMI119N7459 QUICKSILVER RESOURCES INC.

- PLEASANT VALLEY NEIMI119N7459PR0002EU0002FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI119N7467 QUICKSILVER RESOURCES INC.

- HUNT N HAYES NEIMI119N7467PR0003EU0003FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI135N7463 QUICKSILVER RESOURCES INC.

- ELMER FUDD EAST NEIMI135N7463PR0002EU0002FUG001 1.17E

- 03 1.76E

- 03 UNCONTROLLED 0%

NEIMI1375933 ENER VEST OPERATING NEIMI1375933PR0001EU0002SV0020 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1375934 ENER VEST OPERATION NEIMI1375934PR0001EU0002SV0018 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376052 DTE GAS AND OIL COMPANY

- WARNER 22 CPF NEIMI1376052PR0001EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376054 DTE GAS & OIL COMPANY

- ELMIRA 14 NEIMI1376054PR0001EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376057 DTE GAS AND OIL COMPANY

- WARNER 13 NEIMI1376057PR0001EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376058 DTE GAS AND OIL COMPANY

- WARNER 10 NEIMI1376058PR0001EU0002FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376079 PAXTON RESOURCES,
LIVINGSTON 18 CPF NEIMI1376079PR0002EU0002SV0003 5.48E

- 04 8.22E

- 04 UNCONTROLLED 0%

NEIMI1376082 WARD LAKE ENERGY, CHARLTON 11/12, VIENNA 18
CPF NEIMI1376082PR0001EU0006SV0002 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376082 WARD LAKE ENERGY, CHARLTON 11/12, VIENNA 18
CPF NEIMI1376082PR0003EU0008SV0004 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376094 WARD LAKE ENERGY, CHESTER
23 CPF NEIMI1376094PR0001EU0013SV0011 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376181 WARD LAKE ENERGY,
CHARLTON 7 CPF NEIMI1376181PR0001EU0005FUG001 4.43E

- 04 6.65E

- 04 UNCONTROLLED 0%

### Attac hment 1, Page 17

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIMI1376185 ANTRIM DEVELOPMENT CORP

- TOWER NEIMI1376185PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376186 MUSKEGON DEVELOPMENT,
PERCH LAKE NEIMI1376186PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376187 MUSKEGON DEVELOPMENT, NO
LAKE NEIMI1376187PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376188 MUSKEGON DEVELOPMENT,
LITTLE CRAPO LAKE NEIMI1376188PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376189 MUSKEGON DEVELOPMENT, LOWER CHUB LAKE/VIKING
LAKE NEIMI1376189PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376189 MUSKEGON DEVELOPMENT, LOWER CHUB LAKE/VIKING
LAKE NEIMI1376189PR0002EU0005FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376190 MUSKEGON DEVELOPMENT,
CRAPO LAKE NEIMI1376190PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376191 MUSKEGON DEVELOPMENT,
BASS LAKE NEIMI1376191PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI1376221 WARD LAKE ENERGY,
CHARLTON 18

- CPF NEIMI1376221PR0001EU0004SV0002 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376277 ENERVEST OPERATING NEIMI1376277PR0001EU0002SV0005 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376278 ENER VEST OPERATING NEIMI1376278PR0001EU0002SV0002 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376443 ENER VEST OPERATING NEIMI1376443PR0010EU0014SV0012 2.61E

- 05 3.91E

- 05 UNCONTROLLED 0%

NEIMI1376444 ENER VEST OPERATING NEIMI1376444PR0013EU0020SV0018 4.43E

- 04 6.65E

- 04 UNCONTROLLED 0%

NEIMI1376445 ENER VEST OPERATRING NEIMI1376445PR0002EU0004SV0003 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI1376446 ENER VEST OPERATING NEIMI1376446PR0005EU0011SV0008 2.61E

- 05 3.91E

- 05 UNCONTROLLED 0%

NEIMI137B566 KCS RESOURCES, INC.

- OTSEGO
6 CPF NEIMI137B566PR0002EU0014SV0013 2.17E

- 02 3.25E

- 02 UNCONTROLLED 0%

NEIMI137B915 MERIT ENERGY CO.

- HAYES 22
CPF NEIMI137B915PR0001EU0003SV0004 4.82E

- 01 7.23E

- 01 UNCONTROLLED 95%

### Attac hment 1, Page 1 8

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIMI137N596 KCS RESOURCES, INC. OTSEGO
LAKE 26 CPF NEIMI137N596PR0003EU0004SV0003 4.82E

- 01 7.23E

- 01 UNCONTROLLED 95%

NEIMI137N6099 WARD LAKE ENERGY,
LIVINGSTON 34 NEIMI137N6099PR0003EU0007SV0003 4.43E

- 04 6.65E

- 04 UNCONTROLLED 0%

NEIMI137N621 WARD LAKE ENERGY,
CHARLTON 24

- CPF NEIMI137N621PR0001EU0004SV0002 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI137N632 DTE GAS & OIL COMPANY

- ELMIRA 23 NEIMI137N632PR0001EU0006FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMI137N6744 QUICKSILVER RESOURCES INC.

- FONTINALIS 25 NEIMI137N6744PR0006EU0004FUG001 1.62E

- 03 2.43E

- 03 UNCONTROLLED 0%

NEIMI137N7015 QUICKSILVER RESOURCES INC.

- ECHO LAKE 6 CPF NEIMI137N7015PR0002EU0002FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI137N7065 QUICKSILVER RESOURCES INC.

- NADV 1

- 2

- 3 NEIMI137N7065PR0003EU0003FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI137N7184 WARD LAKE ENERGY NEIMI137N7184PR0001EU0006SV0004 6.52E

- 04 9.78E

- 04 UNCONTROLLED 0%

NEIMI137N7284 OIL ENERGY CORP. NEIMI137N7284PR0002EU0003SV0003 2.06E

- 03 3.09E

- 03 UNCONTROLLED 0%

NEIMI137N7341 SCHMUDE OIL INC. NEIMI137N7341PR0002EU0005SV0002 6.00E

- 04 9.00E

- 04 UNCONTROLLED 0%

NEIMI137N7435 ENER VEST OPERATING NEIMI137N7435PR0002EU0004FUG001 2.61E

- 05 3.91E

- 05 UNCONTROLLED 0%

NEIMI137N7456 QUICKSILVER RESOURCES INC

- LUCKY 16 NEIMI137N7456PR0002EU0002FUG001 3.91E

- 04 5.87E

- 04 UNCONTROLLED 0%

NEIMI137N7458 QUICKSILVER RESOURCES INC

- NADV 7 NEIMI137N7458PR0002EU0002FUG001 3.91E

- 04 5.87E

- 04 UNCONTROLLED 0%

NEIMI137N7465 QUICKSILVER RESOURCES

HAYES 34 AKA GRIDIRON SEC 34 NEIMI137N7465PR0002EU0002FUG001 1.25E

- 03 1.88E

- 03 UNCONTROLLED 0%

NEIMI137N7466 QUICKSILVER RESOURCES INC.

- WINTER ANTRIM NEIMI137N7466PR0003EU0003FUG001 4.69E

- 04 7.04E

- 04 UNCONTROLLED 0%

NEIMI137N7488 ENER VEST OPERATING LLC NEIMI137N7488PR0002EU0005SV0002 4.43E

- 04 6.65E

- 04 UNCONTROLLED 0%

NEIMI14392 MERIT ENERGY CO.

- OTSEGO
LAKE 34 NEIMI14392PR0003EU0016FUG001 1.57E

- 02 2.35E

- 02 UNCONTROLLED 0%

### Attac hment 1, Page 19

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIMI2607942 MERIT ENERGY CO.

- KALKASKA
GAS PLANT NEIMI2607942PR0012EU0027SV0001 3.34E

- 02 5.02E

- 02 UNCONTROLLED 0%

NEIMIB5587 MERIT ENERGY COMPANY.

- MAYFIELD 23 NEIMIB5587PR0002EU0014SV0001 5.42E

- 02 8.13E

- 02 UNCONTROLLED 0%

NEIMIB9135 MERIT ENERGY CO.

- BEAR LAKE
13 NEIMIB9135PR0001EU0015FUG001 9.16E

- 02 1.37E

- 01 UNCONTROLLED 0%

NEIMIB9136 MERIT ENERGY CO.

- BEAR LAKE
22 NEIMIB9136PR0001EU0016FUG001 2.53E

- 01 3.80E

- 01 UNCONTROLLED 0%

NEIMIB9142 MERIT ENERGY COMPANY

- CHARLTON 12 NEIMIB9142PR0001EU0011FUG001 5.06E

- 02 7.59E

- 02 UNCONTROLLED 0%

NEIMIB9144 MERIT ENERGY COMPANY

- CHARLTON 4 NEIMIB9144PR0002EU0014FUG001 7.23E

- 02 1.08E

- 01 UNCONTROLLED 0%

NEIMIB9160 MERIT ENERGY COMPANY

- MAPLE GROVE 16 NEIMIB9160PR0001EU0011FUG001 1.18E

- 01 1.77E

- 01 UNCONTROLLED 0%

NEIMIN0539 SUMMIT PETROLEUM CORP

- ROSEBUSH GAS PLANT NEIMIN0539PR0001EU0004SV0002 1.00E

- 01 1.50E

- 01 UNCONTROLLED 0%

NEIMIN0686 STONEY POINT GAS PLANT NEIMIN0686PR0008EU0006FUG001 1.26E+00 1.90E+00 UNCONTROLLED 95%

NEIMIN5949 WHITE LAKE PRODUCTION
FACILITY NEIMIN5949PR0021EU0028FUG001 1.16E+00 1.74E+00 UNCONTROLLED 95%

NEIMIN6015 PARTELLO COMPRESSOR
STATION NEIMIN6015PR0001EU0004FUG001 5.17E

- 02 7.77E

- 02 UNCONTROLLED 0%

NEIMIN6015 PARTELLO COMPRESSOR
STATION NEIMIN6015PR0001EU0009FUG001 2.07E

- 02 3.12E

- 02 UNCONTROLLED 0%

NEIMIN6100 DTE GAS & OIL

- CUSTER
ANTRIM CO2 PLANT NEIMIN6100PR0001EU0003FUG001 1.59E

- 03 2.39E

- 03 UNCONTROLLED 0%

NEIMIN6159 DART OIL & GAS CORP NEIMIN6159PR0001EU0003FUG001 1.87E

- 01 2.81E

- 01 UNCONTROLLED 0%

NEIMIN6160 DART OIL & GAS CORP NEIMIN6160PR0001EU0002FUG001 1.16E

- 01 1.75E

- 01 UNCONTROLLED 0%

NEIMIN6161 DART OIL & GAS CORP NEIMIN6161PR0001EU0003FUG001 2.53E

- 02 3.79E

- 02 UNCONTROLLED 0%

NEIMIN6473 MERIT ENERGY COMPANY

- ALBERT 25 CPF NEIMIN6473PR0007EU0016FUG001 1.28E

- 03 1.92E

- 03 UNCONTROLLED 0%

### Attac hment 1, Page 20

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIOK2089 MADILL GAS PROCESSING LLC NEIOK2089489921289212906 2.14E+00 3.22E+00 UNCONTROLLED 95%

NEIOK2523 ONEOK FIELD SVC NEIOK2523428852008933009 3.51E

- 01 1.04E+00 UNCONTROLLED 95%

NEIOK2529 ONEOK FIELD SVC NEIOK2529535561817117851 4.69E

- 04 7.06E

- 04 UNCONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP NEIOK25795412148344834 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP NEIOK25795412348354835 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEIOK2720 ATLAS PIPELINE MIDCONTINENT
WESTOK LLC NEIOK27205521066546654 1.04E

- 03 1.57E

- 03 UNCONTROLLED 0%

NEITX003AB00 DOLLARHIDE GAS PLANT NEITX003AB00000027000003000003 1.68E

- 03 2.53E

- 03 UNCONTROLLED 0%

NEITX039216U MCFARLAND FACILITY NEITX039216U000008000008000006 3.14E

- 01 3.21E

- 01 UNCONTROLLED 95%

NEITX039216U MCFARLAND FACILITY NEITX039216U000013000013000011 2.50E

- 04 3.77E

- 04 UNCONTROLLED 0%

NEITX039674 HASTINGS WEST COMPRESSOR
STATION NEITX039674000003000003000003 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEITX039675 HASTINGS CENTRAL
COMPRESSOR STATION NEITX039675000003000003000003 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEITX039676 HASTINGS SOUTH COMPRESSOR
STATION NEITX039676000001000001000001 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEITX039682 BROCKMAN TANK BATTERY NEITX039682000003000003000003 3.74E

- 02 5.62E

- 02 UNCONTROLLED 0%

NEITX039682 BROCKMAN TANK BATTERY NEITX039682000004000004000004 5.74E

- 04 8.63E

- 04 UNCONTROLLED 0%

NEITX039692 WEST ANKENMAN SALES POINT NEITX039692000002000002000002 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEITX067CG00 MCLEOD GAS PLANT NEITX067CG00000020000018000013 1.20E

- 01 1.25E

- 01 UNCONTROLLED 0%

NEITX089CR00 HOUSTON CENTRAL GAS PLANT NEITX089CR00000042000023000033 1.56E

- 02 2.35E

- 02 UNCONTROLLED 0%

NEITX089CR00 HOUSTON CENTRAL GAS PLANT NEITX089CR00000043000037000033 2.30E

- 02 3.45E

- 02 UNCONTROLLED 0%

NEITX089CR00 HOUSTON CENTRAL GAS PLANT NEITX089CR00000044000022000033 1.62E

- 02 2.43E

- 02 UNCONTROLLED 0%

NEITX105012K TIPPETT PLANT NEITX105012K000004000017000018 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEITX115009S WELCH CO2 PLANT NEITX115009S000010000010000004 7.82E

- 04 1.18E

- 03 UNCONTROLLED 0%

NEITX161629 BUFFALO CENTRAL GATHERING NEITX161629000002000012000011 8.24E

- 03 1.24E

- 02 UNCONTROLLED 0%

### Attac hment 1, Page 21

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEITX161629 BUFFALO CENTRAL GATHERING NEITX161629000015000010000010 8.24E

- 03 1.24E

- 02 UNCONTROLLED 0%

NEITX167130 ALTA LOMA COMPRESSOR
STATION NEITX167130000003000003000003 5.42E

- 04 8.16E

- 04 UNCONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT NEITX18630000002000030000029 2.99E

- 03 4.50E

- 03 UNCONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT NEITX18630000012000019000018 4.79E

- 01 7.21E

- 01 UNCONTROLLED 95%

NEITX18630 SALT CREEK FIELD GAS PLANT NEITX18630000014000018000017 3.59E

- 03 5.40E

- 03 UNCONTROLLED 0%

NEITX201972B NORTH MILTON NEITX201972B000002000006000006 4.02E

- 04 6.04E

- 04 UNCONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT NEITX241067H000011000007000007 0.00E+00 0.00E+00 UNCONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT NEITX241067H000022000017000017 2.09E

- 03 3.14E

- 03 UNCONTROLLED 0%

NEITX245676 DOORNBOS A #1 PRODUCTION
FACILITY NEITX245676000005000005000005 1.46E

- 04 2.20E

- 04 UNCONTROLLED 0%

NEITX245676 DOORNBOS A #1 PRODUCTION
FACILITY NEITX245676000006000006000006 3.05E

- 01 4.59E

- 01 UNCONTROLLED 95%

NEITX25150 HAYS COMPRESSOR STATION NEITX25150000008000008000007 2.66E

- 04 4.00E

- 04 UNCONTROLLED 0%

NEITX25152 MEADOWS COMPRESSOR SITE NEITX25152000010000010000009 6.26E

- 05 9.41E

- 05 UNCONTROLLED 0%

NEITX25152 MEADOWS COMPRESSOR SITE NEITX25152000011000012000010 1.88E

- 04 2.82E

- 04 UNCONTROLLED 0%

NEITX25154 JOHNSON COUNTY
COMPRESSOR STATION NEITX25154000006000006000006 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEITX25154 JOHNSON COUNTY
COMPRESSOR STATION NEITX25154000007000007000007 1.14E

- 01 1.72E

- 01 UNCONTROLLED 0%

NEITX285067U NORTH WORD GAS PLANT NEITX285067U000003000003000003 2.61E

- 04 3.92E

- 04 UNCONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT NEITX371016P000046000026000013 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT NEITX371016P000047000027000006 4.17E

- 03 6.28E

- 03 UNCONTROLLED 0%

NEITX371019J GREY RANCH TREATING PLANT NEITX371019J000020000020000019 1.13E+01 1.13E+01 UNCONTROLLED 99.75%

NEITX393010G NW MENDOTA GAS PLANT NEITX393010G000032000031000030 6.73E

- 01 6.73E

- 01 UNCONTROLLED 95%

NEITX393010G NW MENDOTA GAS PLANT NEITX393010G000045000048000047 3.29E

- 04 4.94E

- 04 UNCONTROLLED 0%

### Attac hment 1, Page 22

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEITX393010G NW MENDOTA GAS PLANT NEITX393010G000046000049000048 7.56E

- 03 1.14E

- 02 UNCONTROLLED 0%

NEITX42345 ARNOLD 2 1 CENTRAL
PRODUCTION FACILITY NEITX42345000004000004000003 2.09E

- 04 3.14E

- 04 UNCONTROLLED 0%

NEITX461001M CRANE GAS PLANT NEITX461001M000002000003000003 1.65E

- 03 2.48E

- 03 UNCONTROLLED 0%

NEITX461002K WILSHIRE PLANT NEITX461002K000007000007000007 9.18E

- 04 1.38E

- 03 UNCONTROLLED 0%

NEITX461006C BENEDUM GAS PLANT NEITX461006C000057000069000068 3.13E

- 04 4.71E

- 04 UNCONTROLLED 0%

NEITX461058G NORTH CROSS COMP STATION4 NEITX461058G000008000008000011 1.04E

- 03 1.57E

- 03 UNCONTROLLED 0%

NEITX483254 ZYBACH CRYOGENIC PLANT NEITX483254000008000008000008 7.56E

- 04 1.14E

- 03 UNCONTROLLED 0%

NEITX483254 ZYBACH CRYOGENIC PLANT NEITX483254000009000009000009 6.12E

- 03 9.20E

- 03 UNCONTROLLED 0%

NEITXRAB0012 FULLERTON GAS PLANT NEITXRAB0012000014000076000072 5.16E

- 02 7.77E

- 02 UNCONTROLLED 0%

NEITXRAB0012 FULLERTON GAS PLANT NEITXRAB0012000048000042000042 1.04E

- 03 1.57E

- 03 UNCONTROLLED 0%

NEITXRBL0026 PLEDGER FACILITY NEITXRBL0026000015000024000028 1.25E

- 04 1.88E

- 04 UNCONTROLLED 0%

NEITXRBL0026 PLEDGER FACILITY NEITXRBL0026000028000037000031 2.87E+00 2.93E+00 UNCONTROLLED 95%

NEITXRGJ0139 WILLOW SPRINGS PLANT NEITXRGJ0139000007000006000006 1.77E

- 03 2.67E

- 03 UNCONTROLLED 0%

NEITXRHE0012 CONLEY PLANT NEITXRHE0012000005000007000007 4.80E

- 03 7.22E

- 03 UNCONTROLLED 0%

NEITXRHG4368 DURKEE FIELD NEITXRHG4368000001000027000025 5.57E

- 01 5.86E

- 01 UNCONTROLLED 95%

NEITXRJF0027 KINDER MORGAN TEXAS
PIPELINE CO NEITXRJF0027000009000009000010 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEITXRJF0027 KINDER MORGAN TEXAS
PIPELINE CO NEITXRJF0027000010000008000009 1.00E

- 03 1.51E

- 03 UNCONTROLLED 0%

NEITXRNE0062 FLOUR BLUFF STATION NEITXRNE0062000004000022000023 4.78E+00 4.85E+00 UNCONTROLLED 95%

NEITXRNE0062 FLOUR BLUFF STATION NEITXRNE0062000020000006000006 5.22E

- 06 7.84E

- 06 UNCONTROLLED 0%

NEITXRPE0020 PIKES PEAK PLANT NEITXRPE0020000011000008000008 4.12E

- 03 6.20E

- 03 UNCONTROLLED 0%

NEITXRPE0020 PIKES PEAK PLANT NEITXRPE0020000024000017000002 1.69E+00 2.55E+00 UNCONTROLLED 95%

NEITXRPE0042 COYANOSA GAS PLANT NEITXRPE0042000003000015000016 2.92E

- 02 4.39E

- 02 UNCONTROLLED 0%

### Attac hment 1, Page 23

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor † NEITXRSQ0088 JUNO COMPRESSOR STATION NEITXRSQ0088000001000001000001 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEITXRTC0002 TERRELL GAS PLANT NEITXRTC0002000020000020000020 3.13E

- 03 4.71E

- 03 UNCONTROLLED 0%

NEITXRTC0002 TERRELL GAS PLANT NEITXRTC0002000021000021000021 2.81E

- 02 4.22E

- 02 UNCONTROLLED 0%

NEITXRWG0011 KELLERVILLE COMPRESSOR
STATION NEITXRWG0011000035000037000040 9.39E

- 04 1.41E

- 03 UNCONTROLLED 0%

NEITXRWN0107 ASHE COMPRESSOR STATION NEITXRWN0107000002000007000007 1.28E+00 1.35E+00 UNCONTROLLED 95%

NEITXRWN0183 SITZ COMPRESSOR STATION NEITXRWN0183000013000016000013 2.49E

- 03 3.74E

- 03 UNCONTROLLED 0% Group 3(Dehydration units with controlled benzene emissions less than 0.05 tpy)

NEI11208 MIDLAND GAS PLT NEI11208000023000021000014 4.53E

- 02 6.82E

- 02 CONTROLLED 0%

NEI11771 NORTH POINT BOLIVAR FIELD NEI11771000016000016000015 8.68E

- 03 1.31E

- 02 CONTROLLED 0%

NEI11921 WHELAN SOUTH COMP STA NEI11921000009000009000009 5.60E

- 02 8.43E

- 02 CONTROLLED 0%

NEI11924 MORGAN BLUFF FIELD NEI11924000015000015000015 2.13E

- 02 2.13E

- 02 CONTROLLED 0%

NEI11929 OYSTER BAYOU NEI11929000008000022000020 1.04E

- 01 1.08E

- 01 CONTROLLED 0%

NEI11929 OYSTER BAYOU NEI11929000010000021000020 1.02E

- 01 1.06E

- 01 CONTROLLED 0%

NEI12270 HANKAMER NEI12270000045000033000034 1.55E

- 01 1.61E

- 01 CONTROLLED 0%

NEI12281 WEST CLEAR LAKE PEAKING NEI12281000034000022000048 5.74E

- 05 8.63E

- 05 CONTROLLED 0%

NEI12425 POINT BARROW FACILITY NEI12425000001000016000015 1.00E

- 03 1.10E

- 03 CONTROLLED 0%

NEI12470 MIDWAY LANE GAS PLANT NEI12470000024000003000019 1.85E

- 02 2.78E

- 02 CONTROLLED 0%

NEI13106 OZONA GAS PLANT NEI13106000021000022000005 1.67E

- 02 2.17E

- 02 CONTROLLED 0%

NEI2OK285 DCP MIDSTREAM LP NEI2OK2854160916926208 9.91E

- 02 1.49E

- 01 CONTROLLED 0%

NEI2TX07156 C

- 2 PLATFORM NEI2TX07156000003000003000003 2.00E

- 04 2.00E

- 04 CONTROLLED 0%

NEI2TX07186 UMBRELLA POINT

-- TRINITY BAY NEI2TX07186000012000012000011 4.52E

- 02 5.91E

- 02 CONTROLLED 0%

NEI2TX16133 FREESTONE CENTRAL COMPRES NEI2TX16133000002000002000002 2.14E

- 04 3.22E

- 04 CONTROLLED 0%

NEI2TX1619 TEAGUE GAS PLANT NEI2TX1619000062000051000014 1.58E

- 02 2.37E

- 02 CONTROLLED 0%

### Attac hment 1, Page 24

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI6094 CHEVRON USA INC/DELTA
DUCK STN 1 NEI6094090909 7.16E

- 01 7.48E

- 01 CONTROLLED 95%

NEI6449 W RANCH COMP STA VANDERB NEI6449000051000050000070 5.00E

- 04 5.00E

- 04 CONTROLLED 0%

NEI6449 W RANCH COMP STA VANDERB NEI6449000071000070000070 2.45E

- 04 3.69E

- 04 CONTROLLED 0%

NEI6456 KING RANCH PLANT NEI6456000097000022000034 2.77E

- 03 4.17E

- 03 CONTROLLED 0%

NEI6456 KING RANCH PLANT NEI6456000101000019000077 3.06E

- 03 4.60E

- 03 CONTROLLED 0%

NEI6483 KATY GAS PLANT NEI6483000091000023000056 3.15E

- 02 4.74E

- 02 CONTROLLED 0%

NEI6512 PAWNEE GAS PLANT NEI6512000022000023000023 5.77E

- 02 5.87E

- 02 CONTROLLED 0%

NEI6855 AKER PLANT NEI6855000001000023000001 8.00E

- 02 9.00E

- 02 CONTROLLED 0%

NEI7375 FASHING PLANT NEI7375000002000002000001 8.00E

- 04 9.00E

- 04 CONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT NEI7436000035000002000040 9.80E

- 02 9.80E

- 02 CONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT NEI7436000041000049000047 6.30E

- 02 6.30E

- 02 CONTROLLED 0%

NEI7436 HOBART RANCH GAS PLANT NEI7436000042000050000048 6.30E

- 02 6.30E

- 02 CONTROLLED 0%

NEI7500 GORDIN ESTATES COMPR FAC NEI7500000014000010000014 5.00E

- 04 6.00E

- 04 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000039000028000085 2.02E

- 02 2.25E

- 02 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000101000093000066 3.74E

- 02 1.50E

- 01 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000107000093000067 1.71E

- 02 2.57E

- 02 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000108000028000067 1.46E

- 04 2.20E

- 04 CONTROLLED 0%

NEI8007 HAWKINS GAS PLANT NEI8007000109000069000067 5.74E

- 05 8.63E

- 05 CONTROLLED 0%

NEICA0592079 UNION OIL CO OF CALIFORNIA (SI NEICA0592079170013900010 2.23E

- 05 7.16E

- 05 CONTROLLED 0%

NEICA0592118 AERA ENERGY LLC NEICA059211817000200002H 6.54E

- 05 6.54E

- 05 CONTROLLED 0%

NEICA0592118 AERA ENERGY LLC NEICA059211817000300003H 2.43E

- 04 2.44E

- 04 CONTROLLED 0%

NEICO0186 CALPINE NATURAL GAS
COMPANY

- MAMM CREEK NEICO018601001001 6.25E+00 6.91E+00 CONTROLLED 95%

### Attac hment 1, Page 25

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEILA00702000046 PETRO

- HUNT LLC/RAMOS
INVESTMENTS #1 FACILITY NEILA00702000046SCSCSC 5.22E

- 02 7.84E

- 02 CONTROLLED 0%

NEILA00702000048 CHAPARRAL ENERGY INC/J.
AARON NO 2 PRODUCTION
FACILITY NEILA00702000048030303 1.56E

- 01 2.35E

- 01 CONTROLLED 0%

NEILA0075 STONE ENERGY CORP/LAFITTE
FIELD COMPRESSOR STATION TB #5 & CAMP NEILA0075080808 1.30E+00 1.45E+00 CONTROLLED 95%

NEILA0098 LA LAND & EXPLOR

- E LAKE
SAND NEILA0098060606 1.55E

- 02 1.60E

- 02 CONTROLLED 0%

NEILA0123 GULFPORT ENERGY CORP/W
COTE BLANCHE BAY DEHY NEILA0123020202 9.94E

- 01 1.16E+00 CONTROLLED 95%

NEILA0450042 SOURCE PETROLEUM INC/FAUSSE PT CS 2 NEILA0450042121212 1.77E+00 1.89E+00 CONTROLLED 95%

NEILA1010013 CABOT OIL & GAS CORP/BELLE
ISLE BAT #1 NEILA1010013222222 1.64E

- 01 2.18E

- 01 CONTROLLED 0%

NEILA2210126600130 SWIFT ENERGY OPERATING LLC/COTE BLANCHE ISLAND
TANK BATTERY #2 NEILA2210126600130020202 5.22E

- 02 7.84E

- 02 CONTROLLED 0%

NEIMI14392 MERIT ENERGY CO.

- OTSEGO
LAKE 34 NEIMI14392P03S01EU0016FUG002 3.58E

- 02 4.50E

- 02 CONTROLLED 0%

NEIMIN6468 QUICKSILVER RESOURCES INC

- USA KALKASKA 3

- 20 NEIMIN6468P05S01EU0003SV0005 3.15E

- 03 3.97E

- 03 CONTROLLED 0%

NEIMIN6473 MERIT ENERGY COMPANY

- ALBERT 25 CPF NEIMIN6473P07S01EU0016FUG003 2.38E

- 03 2.98E

- 03 CONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP NEIOK25795412048344834 9.70E

- 02 1.46E

- 01 CONTROLLED 0%

NEIOK2579 ENOGEX PROD CORP NEIOK25795412248354835 9.72E

- 02 1.46E

- 01 CONTROLLED 0%

NEIOK2720 ATLAS PIPELINE MIDCONTINENT
WESTOK LLC NEIOK27205521166556655 2.50E

- 02 3.77E

- 02 CONTROLLED 0%

NEITX039674 HASTINGS WEST COMPRESSOR
STATION NEITX039674000004000004000004 5.24E

- 02 7.88E

- 02 CONTROLLED 0%

### Attac hment 1, Page 26

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEITX039675 HASTINGS CENTRAL
COMPRESSOR STATION NEITX039675000004000004000004 5.24E

- 02 7.88E

- 02 CONTROLLED 0%

NEITX039676 HASTINGS SOUTH COMPRESSOR
STATION NEITX039676000004000004000004 5.24E

- 02 7.88E

- 02 CONTROLLED 0%

NEITX039692 WEST ANKENMAN SALES POINT NEITX039692000003000003000003 5.42E

- 02 8.16E

- 02 CONTROLLED 0%

NEITX105012K TIPPETT PLANT NEITX105012K000001000020000020 1.41E

- 02 2.12E

- 02 CONTROLLED 0%

NEITX161629 BUFFALO CENTRAL GATHERING NEITX161629000003000013000011 4.69E

- 02 7.06E

- 02 CONTROLLED 0%

NEITX161629 BUFFALO CENTRAL GATHERING NEITX161629000016000011000010 4.69E

- 02 7.06E

- 02 CONTROLLED 0%

NEITX167130 ALTA LOMA COMPRESSOR
STATION NEITX167130000004000004000004 2.39E

- 03 3.59E

- 03 CONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT NEITX18630000013000019000001 1.29E

- 02 1.94E

- 02 CONTROLLED 0%

NEITX18630 SALT CREEK FIELD GAS PLANT NEITX18630000034000019000031 1.62E

- 02 1.97E

- 02 CONTROLLED 0%

NEITX239041N MAURBRO COMPRSR STN 1 NEITX239041N000013000006000004 8.41E

- 02 8.45E

- 02 CONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT NEITX241067H000008000006000001 0.00E+00 0.00E+00 CONTROLLED 0%

NEITX241067H BROOKELAND GAS PLANT NEITX241067H000009000006000011 0.00E+00 0.00E+00 CONTROLLED 0%

NEITX25150 HAYS COMPRESSOR STATION NEITX25150000007000007000007 3.19E

- 03 4.80E

- 03 CONTROLLED 0%

NEITX25152 MEADOWS COMPRESSOR SITE NEITX25152000009000009000009 1.20E

- 02 1.81E

- 02 CONTROLLED 0%

NEITX25152 MEADOWS COMPRESSOR SITE NEITX25152000012000011000010 4.81E

- 02 7.23E

- 02 CONTROLLED 0%

NEITX285067U NORTH WORD GAS PLANT NEITX285067U000009000009000006 1.10E

- 02 1.10E

- 02 CONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT NEITX371016P000044000014000026 1.37E

- 03 2.06E

- 03 CONTROLLED 0%

NEITX371016P GOMEZ GAS PLANT NEITX371016P000045000006000026 1.23E

- 02 1.85E

- 02 CONTROLLED 0%

NEITX42345 ARNOLD 2 1 CENTRAL
PRODUCTION FACILITY NEITX42345000003000003000003 1.27E

- 01 1.91E

- 01 CONTROLLED 0%

NEITX461001M CRANE GAS PLANT NEITX461001M000038000030000030 8.64E

- 02 1.30E

- 01 CONTROLLED 0%

NEITX461002K WILSHIRE PLANT NEITX461002K000016000016000006 1.83E

- 02 2.15E

- 02 CONTROLLED 0%

NEITX461006C BENEDUM GAS PLANT NEITX461006C000058000070000069 1.45E

- 01 2.18E

- 01 CONTROLLED 0%

### Attac hment 1, Page 27

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in NEI
Dataset Emission

Reduction Required to
Meet MACT Floor †
NEITXRCI0100 SOUTH MAYES STATION NEITXRCI0100000007000009000005 2.00E

- 02 2.33E

- 02 CONTROLLED 0%

NEITXRGJ0139 WILLOW SPRINGS PLANT NEITXRGJ0139000008000007000007 7.16E

- 02 7.25E

- 02 CONTROLLED 0%

NEITXRHG7260 SHORE ACRES COMPRESSOR NEITXRHG7260000001000005000004 5.00E

- 04 6.00E

- 04 CONTROLLED 0%

NEITXRPE0106 YATES FIELD TRACT 75 PLANT NEITXRPE0106000014000013000007 2.61E

- 03 3.92E

- 03 CONTROLLED 0%

### Attac hment 1, Page 28

## ATTACHMENT 2

Summary of NEI Data for Small Glycol Dehydration Units by Facility Natural Gas Transmission and Storage Source Category

### Attac hment 2, Page 1 ATTACHMENT 2

Summary of NEI Data for Small Glycol Dehydration Units by Facility

– Natural Gas Transmission and Storage Source Category

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in
NEI Dataset Emission

Reduction Required to
Meet MACT Floor † Group 1 (Dehydration units with uncontrolled benzene emissions greater than 1 tpy)

NEI32782 DUKE ENERGY FIELD SERVICES, LP NEI32782101212_D 3.56E+00 1.65E+01 UNCONTROLLED 95%

NEI32782 DUKE ENERGY FIELD SERVICES, LP NEI327821013013_D 8.00E+00 1.20E+01 UNCONTROLLED 95%

NEI7412 WAHA PLANT NEI7412000008000026000037 9.28E+00 1.09E+01 UNCONTROLLED 95%

NEICO11678 QUESTAR GAS MANAGEMENT COMPANY NEICO1167801010010 3.42E+00 3.42E+00 UNCONTROLLED 95%

NEICO11678 QUESTAR GAS MANAGEMENT COMPANY NEICO1167801017017 6.15E+00 6.42E+00 UNCONTROLLED 95%

NEICO11678 QUESTAR GAS MANAGEMENT COMPANY NEICO1167801020020 9.71E+00 1.02E+01 UNCONTROLLED 95%

NEIKS13235 ANADARKO GATHERING COMPANY NEIKS13235100219 2.30E+00 3.94E+00 UNCONTROLLED 95%

NEIKS13245 ANADARKO GATHERING COMPANY NEIKS13245101110 2.72E+00 4.63E+00 UNCONTROLLED 95%

NEIWV0050020 DANVILLE COMPRESSOR STATION NEIWV005002001007006 2.58E+01 2.95E+01 UNCONTROLLED 95%

NEIWV0390046 BONHAM COMPRESSOR STATION NEIWV039004601007006 2.21E+01 2.58E+01 UNCONTROLLED 95%

NEIWV0790046 HEIZER COMPRESSOR STATION NEIWV079004601004004 4.92E+00 6.92E+00 UNCONTROLLED 95%

NEIWV0990012 BEECH FORK COMPRESSOR STATION NEIWV099001201006005 2.50E+01 2.87E+01 UNCONTROLLED 95%

NEIWV1090017 BRADLEY COMPRESSOR STATION NEIWV109001701012011 2.68E+01 3.04E+01 UNCONTROLLED 95%

NEIWV20071 CRANBERRY PIPELINE CORPORATION NEIWV2007101005005 1.92E+01 2.26E+01 UNCONTROLLED 95%

* Dehy ID number was created from the NEI by combining the NEI Site ID with the facility process code , emission unit code and emission point code. † Emission reduction required to meet the MACT floor was determined by comparing the dehydration unit’s BTEX emissions to 0.286 tpy (the equivalent to MACT floor of 6.86x10 - 3 lb BTEX/MMscf

- ppmv). If the dehydr ation unit emissions were greater than the MACT floor, control was required regardless of whether the unit was already equipp ed with a control device. It was assumed that the types of controls included a condenser (assumed to achieve 95 percent control) , a vapor recovery unit plus a condenser (assumed to achieve a combined emission reduction of 99.75%). If the facility was already controlled, it was assumed that a vapor recove ry unit (assumed to achieve 95% control) would be installed. It should be noted that if the emission reduction required to achieve a level emissions below the MACT floor was less than 95%, it was assumed f or cost purposes that the facility would install a condenser. Likewise if the required reduction was greater than 95% but less tha n 99.75%, the facility would install a VRU and a condenser.

### Attac hment 2, Page 2

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in
NEI Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIWV20071 CRANBERRY PIPELINE CORPORATION NEIWV2007101007006 1.78E+01 2.15E+01 UNCONTROLLED 95% Group 2(Dehydration units with uncontrolled emissions less than 1 tpy)

NEI11382 MOSS BLUFF HUB PARTNERS NEI11382000011000007000007 1.00E

- 03 1.00E

- 03 UNCONTROLLED 0%

NEI11382 MOSS BLUFF HUB PARTNERS NEI11382000022000018000019 5.22E

- 06 7.84E

- 06 UNCONTROLLED 0%

NEI12421 STATION 581 NEI12421000003000017000017 2.66E

- 04 4.00E

- 04 UNCONTROLLED 0%

NEI12421 STATION 581 NEI12421000015000004000004 5.74E

- 05 8.63E

- 05 UNCONTROLLED 0%

NEI12805 MITCHELL PLANT NEI12805000007000007000001 2.09E

- 03 3.14E

- 03 UNCONTROLLED 0%

NEI13136 L.A. PAN GAS STORAGE FCL. NEI13136000010000013000017 3.39E

- 04 5.10E

- 04 UNCONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA NEI13256000004000004000004 1.25E

- 03 1.88E

- 03 UNCONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA NEI13256000009000008000009 1.25E

- 03 1.88E

- 03 UNCONTROLLED 0%

NEI2IA02

- 007 NATURAL GAS PIPELINE CO. OF AMERICA

- STATION 204 NEI2IA02

- 007160514148003118101 3.65E

- 03 5.49E

- 03 UNCONTROLLED 0%

NEI2IA02

- 007 NATURAL GAS PIPELINE CO. OF AMERICA

- STATION 204 NEI2IA02

- 007160515148002118100 2.61E

- 03 3.92E

- 03 UNCONTROLLED 0%

NEI2IA02

- 007 NATURAL GAS PIPELINE CO. OF AMERICA

- STATION 204 NEI2IA02

- 007160516148001118099 1.62E

- 02 2.43E

- 02 UNCONTROLLED 0%

NEI2KY100052 COLUMBIA NATURAL RESOURCES NEI2KY1000521005005 4.13E

- 01 6.20E

- 01 UNCONTROLLED 0%

NEI2KY100052 COLUMBIA NATURAL RESOURCES NEI2KY1000522003003 4.07E

- 01 6.12E

- 01 UNCONTROLLED 0%

NEI2MS100040 CROSSTEX ACQUISITION MANAGEMENT LP
HEI NEI2MS10004010109999 8.80E

- 02 9.10E

- 02 UNCONTROLLED 0%

NEI2OK3163 ENOGEX GAS GATHERING LLC NEI2OK3163592971522715263 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEI2TX4579 JACKS CREEK TANK BATTERY NEI2TX4579000012000006000006 4.86E

- 02 7.31E

- 02 UNCONTROLLED 0%

NEI2TX4579 JACKS CREEK TANK BATTERY NEI2TX4579000016000002000002 1.46E

- 04 2.20E

- 04 UNCONTROLLED 0%

NEI32782 DUKE ENERGY FIELD SERVICES, LP NEI32782101111_D 9.06E

- 01 5.43E+00 UNCONTROLLED 0%

NEI32782 DUKE ENERGY FIELD SERVICES, LP NEI327821014014_D 5.21E

- 04 7.83E

- 04 UNCONTROLLED 0%

NEI6482 KELSEY STATION NEI6482000005000026000025 2.45E

- 04 3.69E

- 04 UNCONTROLLED 0%

### Attac hment 2, Page 3

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in
NEI Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI6794 STRATTON RIDGE STORAGE FACILITY NEI6794000001000001000001 2.51E+00 2.51E+00 UNCONTROLLED 95%

NEI6794 STRATTON RIDGE STORAGE FACILITY NEI6794000002000002000002 6.26E

- 05 9.41E

- 05 UNCONTROLLED 0%

NEI7119 PANOMA PLANT 1 NEI7119000014000018000028 2.07E

- 03 3.11E

- 03 UNCONTROLLED 0%

NEI7244 ENCINAL STATION NEI7244000014000010000018 4.69E

- 02 7.06E

- 02 UNCONTROLLED 0%

NEI7244 ENCINAL STATION NEI7244000015000011000015 2.09E

- 03 3.14E

- 03 UNCONTROLLED 0%

NEI7412 WAHA PLANT NEI7412000004000030000036 2.30E

- 04 3.45E

- 04 UNCONTROLLED 0%

NEI7537 BUFFALO WALLOW NEI7537000004000006000006 6.41E

- 01 7.63E

- 01 UNCONTROLLED 0%

NEI8351 BETHEL STORAGE COMPRESSOR STATION NEI8351000006000042000043 5.22E

- 06 7.84E

- 06 UNCONTROLLED 0%

NEI8351 BETHEL STORAGE COMPRESSOR STATION NEI8351000007000042000042 5.22E

- 06 7.84E

- 06 UNCONTROLLED 0%

NEI8351 BETHEL STORAGE COMPRESSOR STATION NEI8351000046000003000003 3.13E

- 05 4.71E

- 05 UNCONTROLLED 0%

NEIIL137867A PANHANDLE EASTERN PIPELINE CO NEIIL137867A0100010001 1.43E+00 2.15E+00 UNCONTROLLED 0%

NEIKS12958 NORTHERN NATURAL GAS COMPANY NEIKS129581019019_D 1.36E

- 02 2.04E

- 02 UNCONTROLLED 0%

NEIKS13235 ANADARKO GATHERING COMPANY NEIKS13235101919 1.77E

- 01 2.67E

- 01 UNCONTROLLED 0%

NEILA1130126 AGL RESOURCES/JEFFERSON ISLAND
STORAGE & HUB NEILA1130126050505 5.22E

- 02 7.84E

- 02 UNCONTROLLED 0%

NEILA13384 ACADIAN GAS PIPELINE/GRAND BAYOU
STORAGE FACILITY NEILA13384161616 4.06E

- 01 4.38E

- 01 CONTROLLED 0%

NEILA13384 ACADIAN GAS PIPELINE/GRAND BAYOU
STORAGE FACILITY NEILA13384171717 3.61E

- 01 3.92E

- 01 CONTROLLED 0%

NEIMI117N624 ANR PIPELINE COMPANY WINFIELD DEHY
PLANT NEIMI117N624PR0001EU0001FUG001 6.86E

- 03 1.03E

- 02 UNCONTROLLED 0%

NEIMI117N624 ANR PIPELINE COMPANY WINFIELD DEHY
PLANT NEIMI117N624PR0002EU0001FUG001 5.22E

- 05 7.84E

- 05 UNCONTROLLED 0%

NEIMI14228 OVERISEL COMPRESSOR STATION NEIMI14228PR0004EU0056SV0055 2.14E

- 02 3.22E

- 02 UNCONTROLLED 0%

NEIMI14228 OVERISEL COMPRESSOR STATION NEIMI14228PR0006EU0056SV0055 4.96E

- 04 7.45E

- 04 UNCONTROLLED 0%

NEINE15699 KMIGT BIG SPRINGS STATION NEINE1569901017001 5.22E

- 04 7.84E

- 04 UNKNOWN 0%

### Attac hment 2, Page 4

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in
NEI Dataset Emission

Reduction Required to
Meet MACT Floor †
NEINM16513 LINDRITH COMPRESSOR STATION NEINM1651301002002 5.30E

- 05 1.81E

- 02 UNCONTROLLED 0%

NEINM16705 CEDAR HILL COMPRESSOR STATION NEINM1670501007007 3.81E+00 3.81E+00 UNCONTROLLED 95%

NEINY029R005 TENNECO GAS COMPRESSOR STATION 229 NEINY029R005RC3FPR2290DR0010 1.42E

- 01 1.74E

- 01 UNCONTROLLED 0%

NEINY9026000 INDEPENDENCE STATION NEINY9026000E05EIU00005FUGIT1 6.10E

- 03 6.10E

- 03 UNCONTROLLED 0%

NEINY9026000 INDEPENDENCE STATION NEINY9026000E06EIU00006FUGIT2 6.10E

- 03 6.10E

- 03 UNCONTROLLED 0%

NEINY9027400 BEECH HILL COMPRESSOR STATION NEINY9027400008EIU00008FUGIT4 6.10E

- 03 6.10E

- 03 UNCONTROLLED 0%

NEINY9027400 BEECH HILL COMPRESSOR STATION NEINY9027400009EIU00009FUGIT5 6.10E

- 03 6.10E

- 03 UNCONTROLLED 0%

NEIOK1056 ANADARKO GATHERING CO NEIOK10563968342624262 2.11E

- 02 3.17E

- 02 UNCONTROLLED 0%

NEIOK1272 MIDSTREAM ENGRY SVC LLC NEIOK127212019613411341 1.56E

- 03 2.35E

- 03 UNCONTROLLED 0%

NEIOK1272 MIDSTREAM ENGRY SVC LLC NEIOK12724147213411341 1.07E+00 1.60E+00 UNCONTROLLED 0%

NEIOK1272 MIDSTREAM ENGRY SVC LLC NEIOK1272414751276912784 2.09E

- 03 3.14E

- 03 UNCONTROLLED 0%

NEIOK2371 DCP MIDSTREAM LP NEIOK2371508021430614328 5.66E

- 01 8.52E

- 01 UNCONTROLLED 0%

NEIOK2372 PANHANDLE EASTERN PIPELINE CO NEIOK23723423114330 1.27E+01 1.44E+01 UNCONTROLLED 95%

NEIOK2372 PANHANDLE EASTERN PIPELINE CO NEIOK23725081442314231 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEIOK2374 DCP MIDSTREAM LP NEIOK23745083642544254 2.68E

- 01 4.03E

- 01 UNCONTROLLED 0%

NEIOK401491548 ENOGEX GAS GATHERING LLC NEIOK4014915485387446824682 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEITX065094I BURNETT MAIN COMPRESSOR NEITX065094I000011000004000004 5.22E

- 04 7.84E

- 04 UNCONTROLLED 0%

NEITX161FI01 DEW GATHERING SYSTEM NEITX161FI01000008000008000008 1.36E

- 02 2.05E

- 02 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX NEITXRGA0092000001000027000033 7.82E

- 05 1.18E

- 04 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX NEITXRGA0092000006000022000030 2.50E

- 04 3.77E

- 04 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX NEITXRGA0092000020000008000008 2.92E

- 04 4.39E

- 04 UNCONTROLLED 0%

NEITXRGA0092 LOOP COMPLEX NEITXRGA0092000021000007000007 9.39E

- 05 1.41E

- 04 UNCONTROLLED 0%

NEITXRSQ0095 ESPY COMPRESSOR STATION NEITXRSQ0095000004000004000004 4.28E

- 04 6.43E

- 04 UNCONTROLLED 0%

NEITXRSQ0095 ESPY COMPRESSOR STATION NEITXRSQ0095000005000005000005 3.85E

- 01 5.79E

- 01 UNCONTROLLED 0%

### Attac hment 2, Page 5

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in
NEI Dataset Emission

Reduction Required to
Meet MACT Floor †
NEIUT10253 WESTWATER COMPRESSOR STATION NEIUT102531159894060 1.96E+00 2.01E+00 UNCONTROLLED 95%

NEIWV0395403900050 CARBON COMPRESSOR STATION NEIWV039540390005010033 6.15E

- 04 9.25E

- 04 UNCONTROLLED 0%

NEIWV0395403900050 CARBON COMPRESSOR STATION NEIWV039540390005010044 3.89E

- 02 5.85E

- 02 UNCONTROLLED 0%

NEIWV0990012 BEECH FORK COMPRESSOR STATION NEIWV09900121065 3.43E

- 01 5.16E

- 01 UNCONTROLLED 0% Group 3 (Dehydration units with controlled benzene emissions less than 0.05 tpy)

NEI11118 EAST VILLAGE MILLS NEI11118000001000011000009 1.28E

- 01 2.93E

- 01 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000017000020000095 7.50E

- 03 7.50E

- 03 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000018000021000095 7.50E

- 03 7.50E

- 03 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000019000022000096 7.50E

- 03 7.50E

- 03 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000020000023000096 2.10E

- 02 2.10E

- 02 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000025000027000088 5.40E

- 03 5.50E

- 03 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000028000029000087 5.00E

- 03 5.20E

- 03 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000099000024000098 1.78E

- 02 1.85E

- 02 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000100000025000098 1.80E

- 02 1.87E

- 02 CONTROLLED 0%

NEI13099 BAMMEL GASFIELD NEI13099000101000026000098 1.80E

- 02 1.87E

- 02 CONTROLLED 0%

NEI13136 L.A. PAN GAS STORAGE FCL. NEI13136000042000042000048 4.13E

- 02 4.25E

- 02 CONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA NEI13256000049000017000043 4.29E

- 03 6.45E

- 03 CONTROLLED 0%

NEI13256 HILL LAKE COMPRESSOR STA NEI13256000052000016000043 4.29E

- 03 6.45E

- 03 CONTROLLED 0%

NEI2OK3163 ENOGEX GAS GATHERING LLC NEI2OK3163592981522815264 5.98E

- 02 8.99E

- 02 CONTROLLED 0%

NEI2TX21310 TRI CITIES STA NEI2TX21310000038000001000055 1.88E

- 02 2.83E

- 02 CONTROLLED 0%

NEI2TX21310 TRI CITIES STA NEI2TX21310000039000001000057 1.88E

- 02 2.83E

- 02 CONTROLLED 0%

NEI2TX21310 TRI CITIES STA NEI2TX21310000040000001000056 1.88E

- 02 2.83E

- 02 CONTROLLED 0%

NEI7244 ENCINAL STATION NEI7244000016000012000014 1.63E

- 01 2.46E

- 01 CONTROLLED 0%

NEI7431 NEW YORK STORAGE STATION NEI7431000026000001000035 6.94E

- 02 8.87E

- 02 CONTROLLED 0%

### Attac hment 2, Page 6

NTI_SITE_ID FACILITY NAME Dehy dration Unit ID Number * Baseline
BTEX Emissions (tpy) Baseline

HAP Emissions (tpy) Current Control

Status Listed in
NEI Dataset Emission

Reduction Required to
Meet MACT Floor †
NEI8351 BETHEL STORAGE COMPRESSOR STATION NEI8351000004000044000009 1.40E

- 02 1.52E

- 02 CONTROLLED 0%

NEIKS13245 ANADARKO GATHERING COMPANY NEIKS13245101010 5.73E

- 02 8.62E

- 02 CONTROLLED 0%

NEILA0010059 MARKET HUB PARTNERS LP/EGAN LA #1
PROJECT NEILA0010059R2R2R2 5.22E

- 02 7.84E

- 02 CONTROLLED 0%

NEITX157266K KATY HUB & STORAGE PLANT NEITX157266K000024000023000012 2.00E

- 02 2.00E

- 02 CONTROLLED 0%

NEITX157266K KATY HUB & STORAGE PLANT NEITX157266K000027000026000022 1.53E

- 03 2.30E

- 03 CONTROLLED 0%

NEITX161FI01 DEW GATHERING SYSTEM NEITX161FI01000009000009000008 1.66E

- 02 2.49E

- 02 CONTROLLED 0%

NEITX36562 BECKVILLE COMPRESSOR STATION NEITX36562000011000011000011 9.13E

- 02 1.37E

- 01 CONTROLLED 0%