                 United States Environmental Protection Agency
                              Statement of Basis
                             Air Pollution Control
                     Part 71 Title V Permit to Operate for
                          River Bend Dehydration Site
                        Permit No. V-UO-000026-2022.00

The purpose of this document is to set forth the legal and factual basis for permit conditions, including references to applicable provisions of the Clean Air Act (CAA or Act) and implementing regulations of the CAA title V operating permit program at 40 C.F.R. part 71 (Part 71). This document also gives the derivation of conditions as required by 40 C.F.R. § 71.11(b).

EPA Authority to Issue Part 71 Permits

All major stationary sources of air pollution and certain other sources are required to apply for title V operating permits that include emission limitations and other conditions as necessary to assure compliance with applicable requirements of the CAA, including the requirements of the applicable State Implementation Plan (SIP). CAA §§ 502(a) and 504(a). The title V operating permit program does not generally impose new substantive air quality control requirements (referred to as "applicable requirements"), but does require permits to contain monitoring, recordkeeping, reporting and other requirements to assure source' compliance with applicable requirements. 57 FR 32250, 32251 (July 21, 1992). One purpose of the title V operating permit program is to "enable the source, States, the EPA, and the public to understand better the requirements to which the source is subject, and whether the source is meeting those requirements." 57 FR 32251. Thus, the title V operating permit program is a vehicle for ensuring that air quality control requirements are appropriately applied to the source emission units and for assuring compliance with such requirements.

Part 71 programs for Indian country - The Administrator will implement and enforce an operating permits program in Indian country, as defined in § 71.2, when an operating permits program which meets the requirements of Part 70 of this chapter has not been explicitly granted full or interim approval by the Administrator for Indian country.

Facility Information and Description

Applicant and Stationary Source Information

Table 1: Applicant Information
Owner/Operator
Facility SIC/NAIC Code: 1311
Utah Gas Corporation
133 E 1000N
Roosevelt, Utah  84066
River Bend Dehydration Site
Latitude: 39.94851N
Longitude: 109.77057W

Table 2: Stationary Source Information
Responsible Official
Facility Contact
Russ Knight
President
Utah Gas Corporation
760 Horizon Drive, Suite 400
Grand Junction, Colorado  81506
(970) 749-9750
Ken Secrest
Regulatory Coordinator
Utah Gas Corporation
133 E 1000N
Roosevelt, Utah  84066
(970) 675-4440 Ext. 7947

Facility Description
River Bend Dehydration Site (River Bend) is owned by Utah Gas Corporation (UGC) and is located on the Uintah and Ouray Indian Reservation in Uintah County, Utah. The facility was initially permitted on September 22, 2017, and currently operates under the Part 71 permit No. V-UO-000026-2011.00.
River Bend receives compressed natural gas produced from area wells up to a line pressure of 850 to 1,000 pounds per square inch gauge (psig) through 6-inch and 10-inch gathering flowlines. The gas is first processed through two 2-phase separators followed by a triethylene glycol (TEG) dehydration system. The produced liquids from the inlet separators are sent to a 30,000-gallon pressurized flash separator in order to prevent the flash emissions from being vented to the atmosphere. The separated liquids are then routed from the pressurized flash separator to either of two onsite 400-barrel atmospheric liquid storage tanks. These storage tanks are temporally utilized until the liquids can be transported by trucks offsite.
After inlet separation, the separated gas is routed to a TEG natural gas dehydration system where water is removed from the natural gas stream. The emissions from the TEG natural gas dehydration system are controlled by a thermal oxidizer and a benzene, toluene, ethylbenzene and xylene (BTEX) emissions control system. After the TEG natural gas dehydration system, the natural gas leaves the River Bend site via a metered sales pipeline.
River Bend also includes two production wellsites RBU 7-15E (Figure 1 below) and RBU 11-15E (Figure 2 below). Each of these two wellsites consists of one <= 400-barrel storage tank and natural gas fired heaters. RBU 7-15E also operates a small 0.20 million standard cubic feet per day (MMscfd) TEG natural gas dehydration system. Both RBU 7-15E and RBU 11-15E are located on separate surface sites within a quarter mile of River Bend. Tap-1 Compressor Station (Tap-1) (Figure 3 below) is an off-site compressor station that receives the gas produced from the two wellsites and consists of two natural gas-fired compression engines, two condensate storage tanks, two natural gas-fired tank heaters, one separator heater and condensate truck loading. Tap-1 is also located within a quarter mile of River Bend.

Figure 1  -  RBU 7-15E Wellsite Process Flow Diagram

Figure 2  -  RBU 11-15E Wellsite Process Flow Diagram

Figure 3  -  Tap 1 Compressor Station Process Flow Diagram

Figure 4  -  River Bend Dehydration Site Process Flow Diagram

Figure 5  -  Site Location Diagram

Title V Major Source Status
The Part 71 Permit Program applies to major sources, as defined in 40 C.F.R. § 71.2. The title V major source thresholds, as determined by pollutant-specific potential to emit (PTE), for criteria pollutants are 100 tons per year (tpy) and for HAP are 10 tons/year for a single HAP or 25 tons/year for any combination of HAP. According to the information submitted in UGC's River Bend Part 71 application, the site is a major title V source for HAP, as the PTE of dehydration unit RBD-1, and therefore, the facility-wide PTE, exceeds the major source thresholds for individual HAP.

Source Determination
At 40 C.F.R. § 71.2, a major source is generally defined as any stationary source (or any group of stationary sources) that is located on one or more contiguous or adjacent properties, is under common control of the same person (or persons under common control) and belongs to a single major industrial grouping. On June 3, 2016, the EPA published a final rule clarifying when oil and natural gas sector equipment and activities must be deemed a single source when determining whether major source permitting programs (prevention of significant deterioration (PSD) and New Source Review preconstruction permit programs, and the Part 71 Permit Program) apply (81 FR 35622). By defining the term "adjacent," the rule specifies that equipment and activities in the oil and natural gas sector that are under common control will be considered part of the same source if they are located on the same surface site or on individual surface sites that share equipment and are within a quarter mile of each other.
According to information provided by UGC, River Bend (Figure 4 above), Tap-1 Compressor Station (Figure 3 above), RBU 7-15E wellsite (Figure 1 above), RBU 11-15E wellsite (Figure 2 above), are located within a quarter mile of River Bend and share equipment with River Bend. In addition, the RBU 6-15E wellsite is located on the same surface site as River Bend. Therefore, the EPA has determined that the RBU 7-15E wellsite, RBU 11-15E wellsite, and Tap-1 Compressor Station are adjacent to River Bend and thus part of the same stationary source.
Area Classification  -  Local Air Quality and Attainment Status
River Bend is located within the exterior boundaries of Uintah and Ouray (U&O) Indian Reservation and within an area designated as Marginal nonattainment for the 2015 ozone National Ambient Air Quality Standard (NAAQS) of 70 parts per billion. The exact location for this source is Latitude 39.94851N, Longitude 109.77057W, in Uintah County, Utah.
Tribal Reservation Contact
Mike Natchees
Air Quality Program Director
Ute Indian Tribe
P.O. Box 70
Fort Duchesne, Utah  84026
(435) 725-4974 or<EMAIL_ADDRESS>
Identification of Emission Generating Activities
The Part 71 Permit Program allows the Permittee to separately list in the permit application units or activities that qualify as "insignificant" based on potential emissions below 2 tons tpy for all regulated pollutants that are not listed as HAP under section 112(b) and below 1,000 lbs/year or the de minimis level established under section 112(g), whichever is lower, for HAP. However, the application may not omit information needed to determine the applicability of or to impose, any applicable requirement. Units and activities that qualify as "insignificant" for the purposes of the Part 71 application are in no way exempt from applicable requirements or any requirements of the Part 71 permit. Tables 3 and 4 list emission units and emission generating activities, including any air pollution control devices.

Table 3: Emission Units and Emission Generating Activities

                                  Unit I.D.

                                  Description

                               Control Equipment
                                     RBD-1
45 MMscfd* TEG* Dehydration Unit (River Bend)
Serial #: 8156  	                        Installed: 1/17/2010
                               Thermal Oxidizer
                                     RBT-1
400 bbl* Condensate Storage Tank (River Bend)
Serial #: 1764                              Installed: 12/15/2009
                                     None
                                     RBT-2
400 bbl Condensate Storage Tank (River Bend)
 Serial #: 1765                              Installed: 12/15/2009
                                     None
                                     RBL-1
Condensate Truck Loading Emissions (River Bend)
                                     None
                                     RBF-1
Fugitive Emissions (River Bend)
                                     None
                                 RBU 6-15E F-1
Fugitive Emissions (RBU 6-15E)
                                     None
                                 RBU 7-15E F-1
Fugitive Emissions (RBU 7-15E)
                                     None
                                RBU 11-15E D-1
0.20 MMscfd TEG Dehydration Unit (RBU 11-15E)
Installed: 2007
                                     None
                                RBU 11-15E F-1
Fugitive Emissions (RBU 11-15E)
                                     None
                                RBU 11-15E P-1
Pneumatic Pump Emissions (RBU 11-15E)
                                     None
                                     T1C-1
Caterpillar 3516 LE; 1,340 hp (Tap-1)
4-Stroke Lean-Burn Reciprocating Internal Combustion Engines
Natural Gas-Fired
Serial No. WPT00244		Installed: 6/25/2021
				Mfd Date: 5/2/2007
                              Oxidation Catalyst
                               (not enforceable)
                                     T1C-2
Caterpillar 3516 LE; 1,340 hp (Tap-1)
4-Stroke Lean-Burn Reciprocating Internal Combustion Engines
Natural Gas-Fired
Serial No. 4EK03582		Installed: 7/18/2013
				Mfd Date: 8/12/2001
                              Oxidation Catalyst
                               (not enforceable)
                                     T1T-1
300 bbl Condensate Storage Tank (Tap-1)
 Serial #: 2024                                  Installed: 6/18/2012
                                     None
                                     T1T-2
300 bbl Condensate Storage Tank (Tap-1)
 Serial #: 8S06401-02                       Installed: 6/18/2012
                                     None
                                T1P-1 and T1P-2
Two (2) Heat Trace Pneumatic Pumps (Tap-1)
                                     None
                                     T1F-1
Fugitive Emissions (Tap-1)
                                     None

Table 4: Insignificant Emission Units[*]
                                                   Description
                Capstone 65 kW Microturbine Genset (River Bend)
            1.5 MMBtu/hr TEG Dehydration Unit Reboiler (River Bend)
         Six 0.25 MMBtu/hr Tank Heaters (River Bend, RBU 7-15E, Tap-1)
 	3.0 MMBtu/hr Heater for Thermal Oxidizer (River Bend)
                    Pipeline Pigging Operations (River Bend)
                   0.50 MMBtu/hr Separator Heater (RBU 7-15E)
                      Condensate Truck Loading (RBU 7-15E)
                      400-bbl Condensate Tank (RBU 7-15E)
            0.1 MMBtu/hr TEG Dehydration Unit Reboiler (RBU 11-15E)
            Two 0.25 MMBtu/hr Separator Heaters (RBU 11-15E, Tap-1)
                     Condensate Truck Loading (RBU 11-15E)
                      300-bbl Condensate Tank (RBU 11-15E)
                   Capstone 65 kW Microturbine Genset (Tap-1)
                   Condensate Truck Loading Emissions (Tap-1)
                     Compressor Blowdown Emissions (Tap-1)
                        500 bbl Condensate Tank (Tap-1)
 	300 bbl Condensate Tank (Tap-1)
                   Two 400 bbl Condensate Tanks (River Bend)
                    Thermal Oxidizer for RBD-1 (River Bend)
*Insignificant emission units can change at the facility as long as the new or replacement units meet the criteria for insignificance, and UGC supplies information as required under 40 C.F.R. part 71 and this permit. The insignificant emission unit status does not exempt these emission units from the requirements of any standards that may apply under 40 C.F.R. parts 60 or 63.

Permitting, Construction and Compliance History
River Bend is owned by UGC and is located on the Uintah and Ouray Indian Reservation in Uintah County, Utah. The facility was initially permitted on September 22, 2017, and currently operates under the title V Operating Permit V-UO-000026-2011.00 which expired on September 22, 2022. A timely application to renew the Part 71 permit was received by the EPA on February 8, 2022, and was deemed complete on March 3, 2022.
Emission Inventory

Pursuant to 40 C.F.R. § 52.21, PTE is defined as the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation, or the effect it would have on emissions, is federally enforceable. Independently enforceable applicable requirements are considered enforceable to the extent that the source is in compliance with the standard. In addition, beneficial reductions in non-targeted pollutants resulting from compliance with an independently enforceable applicable requirement may be counted towards PTE provided the emission reduction of the non-targeted pollutant is enforceable as a practical matter and compliance is being met. See the 1995 guidance memo signed by John Seitz, Director of the Office of Air Quality Planning and Standards titled, "Options for Limiting Potential to Emit of a Stationary Source under Section 112 and Title V of the Clean Air Act."

UGC reported the controlled emission unit-specific PTE in their Part 71 renewal permit application. The controlled emissions in Table 5 are based on the legally and practicably enforceable requirements set forth in this draft permit.

Table 5: Potential-to-Emit with Legally and Practicably Enforceable Controls

                        Regulated Air Pollutants (tpy)

                                   Unit I.D.
                                      NOX

                                      VOC

                                      SO2

                                PM/ PM2.5/PM10

                                      CO

                                    CH2O
                                   Total HAP

                                  RBD-1[1,] A
                                       -
                                     8.03
                                       -

                                       -
                                       -
       5.12
                            RBU 11-15E D-1[1][, C]
                                       -
                                     10.54
                                       -

                                       -
                                       -
       3.90
                                  RBL-1[1,] A
                                       -
                                     2.44
                                       -

                                       -
                                       -
        0.52
                                 RBF-1[1,][A]
                                       -
                                     5.68
                                       -

                                       -
                                       -
        0.93
                             RBU 7-15E F-1[1][, C]
                                       -
                                     4.13
                                       -

                                       -
                                       -
        0.28
                            RBU 11-15E F-1[1][, C]
                                       -
                                     4.13
                                       -

                                       -
                                       -
        0.28
                                 T1F-1[1][, D]
                                       -
                                     2.38
                                       -

                                       -
                                       -
        0.31
                                 T1C-1[1][, D]
                                     19.41
                                     7.89
                                     0.03
                                     0.50
                                     33.00
                                     3.62
        4.40
                                 T1C-2[1][, D]
                                     16.66
                                     7.88
                                     0.02
                                     0.42
                                     29.43
                                     3.22
        3.88
                            RBU 11-15E P-1[1][, C]
                                       -
                                     6.57
                                       -

                                       -
                                       -
        0.38
                   Capstone 65kW Microturbine Genset [2,][A]
                                     0.13
                                     0.18
                                   <0.01

                                     0.03
                                     1.68
                                     0.16
                                     0.20
              1.5 MMBtu/hr* TEG Dehydration Unit Reboiler [2,][A]
                                     0.64
                                     0.04
                                   <0.01

                                     0.05
                                     0.54
                                   <0.01
                                   <0.01
                 Six 0.25 MMBtu/hr Tank Heaters 2, [A][, B, C]
                                     0.66
                                   <0.01
                                   <0.01
                                   <0.01
                                     0.54
                                   <0.01
                                   <0.01
                3.0 MMBtu/hr Heater for Thermal Oxidizer[2,][A]
                                     1.29
                                     0.07
                                   <0.01

                                     0.10
                                     1.08
                                   <0.01
                                   <0.01
                      Pipeline Pigging Operations [2,][A]
                                       -
                                     0.08
                                       -
                                       -
                                       -
                                       -
                                   <0.01
                     Two 400 bbl* Condensate Tanks[2,][A]
                                       -
                                     0.08
                                       -
                                       -
                                       -
                                       -
                                     0.02
                       Thermal Oxidizer for RBD-1[2,][A]
                                     0.94
                                   <0.01
                                       -
                                      0.7
                                     0.79
                                       -
                                       -
                      0.50 MMBtu/hr Separator Heater[2,B]
                                     0.21
                                     0.01
                                   <0.01
                                     0.02
                                     0.18
                                   <0.01
                                   <0.01
                         Condensate Truck Loading[2,B]
                                       -
                                     0.16
                                       -
                                       -
                                       -
                                       -
                                     0.03
                         400-bbl Condensate Tank[2,B]
                                       -
                                     0.70
                                       -
                                       -
                                       -
                                       -
                                     0.03
                0.1 MMBtu/hr TEG Dehydration Unit Reboiler[2,C]
                                     0.04
                                   <0.01
                                   <0.01
                                   <0.01
                                     0.04
                                   <0.01
                                   <0.01
                 Two 0.25 MMBtu/hr Separator Heaters[2,C][,D]
                                     0.11
                                   <0.01
                                   <0.01
                                   <0.01
                                     0.09
                                   <0.01
                                   <0.01
                         Condensate Truck Loading[2,C]
                                       -
                                     0.16
                                       -
                                       -
                                       -
                                       -
                                     0.03
                         300-bbl Condensate Tank[2,C]
                                       -
                                     0.70
                                       -
                                       -
                                       -
                                       -
                                     0.03
                    Capstone 65 kW Microturbine Genset[2,D]
                                     0.13
                                     0.18
                                   <0.01
                                     0.03
                                     1.68
                                     0.16
                                     0.20
                    Condensate Truck Loading Emissions[2,D]
                                       -
                                     0.35
                                       -
                                       -
                                       -
                                       -
                                     0.08
                      Compressor Blowdown Emissions[2,D]
                                       -
                                     1.60
                                       -
                                       -
                                       -
                                       -
                                     0.07
      One 500 bbl Condensate Tank & one 300 bbl Condensate Tank[2,D]
                                       -
                                     0.07
                                       -
                                       -
                                       -
                                       -
                                     0.02
                      Fugitive Emissions[2,][A][,B,C,][D]

                                     16.32

                                     1.80
                                     TOTAL
                                     40.33
 64.12
                                     0.08
                                     1.28
                                     69.14
                                     7.16
       20.72
[1] Significant Emission Sources
[2] Insignificant Emission Sources
[A] River Bend, [B] RBU 7-15E, [C] EBU 11-15E, [D] Tap-1

Regulatory Analysis

The discussions in the following sections are based on the information provided by UGC in their Part 71 renewal application, certified to be true and accurate by the Responsible Official of this facility.

PSD, 40 C.F.R. Part 52.21
The Prevention of Significant Deterioration Permit Program at 40 C.F.R. part 52 is a preconstruction review requirement of the CAA that applies to proposed projects that are sufficiently large (in terms of emissions) to be a "major" stationary source or "major" modification of an existing stationary source. Source size is defined in terms of "potential to emit," which is its capability at maximum design capacity to emit a pollutant, except as constrained by existing legally and practically enforceable conditions applicable to the source. A new stationary source or a modification to an existing minor stationary source is major if the proposed project has the PTE of any pollutant regulated under 40 C.F.R. part 52 in amounts equal to or exceeding specified major source thresholds, which are 100 tpy for 28 listed industrial source categories and 250 tpy for all other sources. PSD also applies to modifications at existing major sources that cause a "significant net emissions increase" at that source. Significance levels for each pollutant are defined in the PSD regulations at 40 C.F.R. § 52.21.
According to the information provided by UGC in their Part 71 renewal application, at the time of its construction and subsequent modifications, River Bend was not a major source of emissions with respect to the PSD Permit Program as the PTE did not exceed the major source thresholds of criteria pollutants regulated under PSD Permit Program. As such, the source was not subject to the preconstruction permitting requirements of the PSD Permit Program.
NSR, 40 C.F.R. Part 49
40 C.F.R. § 49.166 - Federal Major New Source Review Program for Nonattainment Areas in Indian Country:
The Federal Major NSR Program for Nonattainment Areas in Indian Country (NNSR Permit Program) at 40 C.F.R. part 49 is a preconstruction review requirement of the CAA that applies to proposed projects that are sufficiently large (in terms of emissions) to be a "major" stationary source or "major modification" of an existing stationary source in an area that the EPA has designated nonattainment for a NAAQS (See 40 C.F.R. § 49.167). Similar to the PSD Permit Program, source size is defined in terms of PTE, but a new stationary source or a modification to an existing stationary source is major if the proposed project has the PTE for any pollutant regulated under the 40 C.F.R. part 49 requirements in amounts equal to or exceeding specified major source thresholds defined in 40 C.F.R. part 51, appendix S.
On April 30, 2018, the EPA designated portions of the Indian country lands within the U&O Reservation as Marginal nonattainment for the 2015 ozone NAAQS effective on August 3, 2018. Tap 1 is located within that marginal ozone nonattainment area. Appendix S lists the marginal ozone nonattainment major source threshold for VOC or NOX emissions as 100 tpy. As explained previously, Tap 1 was not considered a major source with respect to the PSD Permit Program at the time of construction and it is also not a major source with respect to the NNSR Permit Program, as the PTE of VOC and NOX, precursor pollutants to ozone, are both below 100 tpy with respect to the Marginal ozone nonattainment area within which the River Bend facility is located.
40 C.F.R. § 49.151 - Federal Minor New Source Review Program in Indian Country:
The Federal Minor New Source Review (MNSR) Permit Program at 40 C.F.R. part 49, subpart C (§§49.151 through 49.165), is a preconstruction review requirement of the CAA that applies to all new and modified minor sources, synthetic minor sources and minor modifications at major sources, located in Indian country where no EPA-approved program is in place. True minor sources and modifications and minor modifications at existing major sources are proposed projects that have PTE for any pollutant regulated under the MNSR Permit Program that are below the major source thresholds in the PSD Permit Program or the NNSR Permit Program at 40 C.F.R. part 49, subpart C, and above the minor source thresholds in Table 1 of 40 C.F.R. 49.153 (thresholds differ depending on the pollutant). The MNSR Permit Program also provides the EPA authority to establish enforceable restrictions for an otherwise major source to establish that source as a synthetic minor source for NSR-regulated pollutants or HAP for the purposes of the PSD, NNSR or title V Permit Programs, or for the purposes of major source requirements of the NESHAP at 40 C.F.R. part 63. Additionally, the MNSR Permit Program established a Federal Implementation Plan (FIP) (§§ 49.101 through 49.105) for true minor sources in the oil and natural gas production and natural gas processing segments that are in Indian country.
River Bend is currently a true minor source and was originally constructed and commenced operations before August 30, 2011. As such, River Bend was registered as an existing true minor source per 40 C.F.R. 49.160 (registration number: REG-UO-000026-2013.001). No other pre-construction requirements applied to River Bend under the MNSR Permit Program.
NSPS, 40 C.F.R. Part 60
40 C.F.R. Part 60, Subpart A: This subpart applies to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication of any standard in 40 C.F.R. part 60 (Part 60). The general provisions under subpart A apply to sources that are subject to the specific subparts of Part 60.

Based on the information provided by UGC in their Part 71 application, River Bend is not subject to any specific subparts of Part 60, therefore, the General Provisions of Part 60 do not apply.

NESHAP, 40 C.F.R. Part 63
40 C.F.R. Part 63, Subpart A: The requirements of 40 C.F.R. part 63, subpart A apply to sources that are subject to the specific subparts of 40 C.F.R. part 63.
As explained below, the TEG dehydration unit, emissions unit RBD-1, is subject to 40 C.F.R. part 63, subpart HH; and the reciprocating internal combustion engines (RICE), emissions units T1C-1 and T1C-2, are subject to 40 C.F.R. part 63, subpart ZZZZ; therefore, the General Provisions of 40 C.F.R. part 63 apply.
40 C.F.R. Part 63, Subpart HH (Subpart HH or MACT HH): This subpart establishes emission standards for the control of HAP emissions from affected units located at natural gas production facilities that process, upgrade or store natural gas prior to the point of custody transfer, or that process, upgrade or store natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user. The affected units are glycol dehydration units, storage vessels with the potential for flash emissions (as defined in the rule) and the group of ancillary equipment and compressors intended to operate in volatile HAP service which are located at natural gas processing plants.
Based on the information provided by UGC in their Part 71 application, River Bend, RBU 7-15E wellsite, RBU 11-15E wellsite, and the Tap-1 compressor station do not operate any storage vessels with the potential for flash emissions (as defined in the rule). Uncontrolled emissions from dehydration unit RBD-1 exceed the major source thresholds for individual HAP. Therefore, dehydration unit RBD-1 is subject to the major source requirements of this subpart for large glycol dehydration units.
As defined in § 63.761, emissions from processes, operations or equipment that are not part of the same facility, as defined in this section, shall not be aggregated to determine whether such emission points are major sources as defined in Subpart HH. Therefore, the RBU 11-15E wellsite is an area source under the rule and dehydration unit RBU 11-15E D-1 is subject to the area source requirements of the rule. However, dehydration unit RBU 11-15E D-1 meets the exemption criteria in § 63.764(e) because, according to the information provided by UGC in their Part 71 application, the actual annual average flowrate of natural gas to the dehydration unit is less than 85,000 standard cubic meters per day. UGC is subject to the recordkeeping requirements for the exemption criteria at §63.774(d)(1).
40 C.F.R. Part 63, Subpart ZZZZ (Subpart ZZZZ): This subpart establishes emission standards and operating limitations for HAP emissions from stationary spark ignition (SI) and compression ignition (CI) reciprocating internal combustion engines (RICE). Subpart ZZZZ applies to RICE with greater than 500 hp constructed after December 19, 2002, and RICE with less than 500 hp constructed after June 12, 2006. All engines onsite fall into either of these categories.
Based on the information provided by UGC in their Part 71 application, there are no RICE operating at River Bend, RBU 7-15E wellsite or RBU 11-15E wellsite. According to the regulations at § 63.6585(b), a major source of HAP emissions is a plant site that emits or has the potential to emit any single HAP at a rate of 10 tons or more per year or any combination of HAP at a rate of 25 tons or more per year, except that for oil and natural gas production facilities, a major source of HAP emissions is determined for each surface site. Since the Tap-1 compressor station is not located on the same surface site as River Bend, neither the emissions from River Bend nor the wellsites shall be aggregated for the purposes of determining a major source of HAP. Therefore, the TAP 1 Compressor Station is an area source of HAP.

According to the information provided by UGC in their Part 71 renewal permit application, Tap-1 emission units T1C-1 and T1C-2 are both RICE with a maximum capacity of 1,340 hp, and were manufactured in May 2007 and August 2001, respectively, and installed in June 2021 and July 2013, respectively. Therefore, the RICE T1C-1 and T1C-2 are subject to the area source requirements of this subpart.

40 C.F.R. Part 64 (Compliance Assurance Monitoring (CAM) Rule): Pursuant to requirements concerning enhanced monitoring and compliance certification under the CAA, the EPA promulgated regulations to implement compliance assurance monitoring (CAM) for major stationary sources of air pollution, for purposes of title V permitting that are required to obtain operating permits under Part 71. The rule requires owners or operators of such sources to conduct monitoring that provides a reasonable assurance of compliance with applicable requirements under the CAA. The effective date of this rule is November 21, 1997.

 CAM Applicability

According to 40 C.F.R. § 64.2(a), CAM applies to each pollutant specific emission unit (PSEU) located at a major source which is required to obtain a Part 71 permit if the unit satisfies all of the following criteria:

       The unit is subject to an emission limitation or standard for the applicable regulated air pollutant other than an emissions limitation or standard that is exempt under 40 C.F.R. § 64.2(b)(1);

       The unit uses a control device to achieve compliance with any such limit or standard; and

       The unit has pre-control device emissions of the applicable regulated pollutant that are equal to or greater than 100% of the amount, in tpy, required for a source to be classified as a major Title V source.

 CAM Plan Submittal Deadlines

 Large PSEUs. A CAM plan submittal for all PSEUs with the PTE (taking into account control devices) of any one regulated air pollutant in an amount equal to or greater than 100% of the amount, in tpy, required for a source to be classified as a major source, is due at the following times:

             On or after April 20, 1998, if by that date, a Part 71 application has either:

                   Not been filed; or
                   Not yet been determined to be complete.

             On or after April 20, 1998, if a Part 71 permit application for a significant modification is submitted with respect to those PSEUs for which the requested permit revision is applicable; or

             Upon application for a renewed Part 71 permit and a CAM plan has not yet been submitted with an initial or a significant modification application, as specified above.

 Other PSEUs. A CAM Plan must be submitted for all PSEUs that are not large PSEUs, but are subject to this rule, upon application for a Part 71 renewal permit.

According to information provided by UGC in their Part 71 renewal permit application, RBD-1 is a PSEU with pre-controlled emissions that equal or exceed the 100% VOC and HAP thresholds. However, as explained above 40 C.F.R. part 63, subpart HH, RBD-1 meets the exemption because the actual annual average flowrate of natural gas to the TEG dehydration unit is less than 85,000 standard cubic meters per day. There are no other PSEUs at River Bend that have potential pre-control emissions in an amount equal to or greater than 100% of the major source thresholds. Therefore, there are no emission units at River Bend that are subject to CAM requirements.

40 C.F.R. Part 68 (Chemical Accident Prevention Provisions): This rule applies to stationary sources that manufacture, process, use, store or otherwise handle more than the threshold quantity of a regulated substance in a process. Regulated substances include 77 toxic and 63 flammable substances which are potentially present in the natural gas stream entering the facility and in the storage vessels located at the facility. The quantity of a regulated substance in a process is determined according to the procedures presented under 40 C.F.R. § 68.115. 40 C.F.R. §§ 68.115(b)(l) and (2)(i) which indicate that toxic and flammable substances in a mixture do not need to be considered when determining whether more than a threshold quantity is present at a stationary source if the concentration of the substance is below 1% by weight of the mixture.
40 C.F.R. § 68.115(b)(2)(iii) indicates that prior to entry into a natural gas processing plant, regulated substances in naturally occurring hydrocarbon mixtures need not be considered when determining whether more than a threshold quantity is present at a stationary source. Naturally occurring hydrocarbon mixtures include condensate, field gas and produced water.

Based on the information provided in UGC's Part 71 renewal permit application, River Bend does not have regulated substances above the threshold quantities in this rule and, therefore, is not subject to the requirement to develop and submit a risk management plan.

EPA Trust Responsibility  -  consultation requirements
Endangered Species Act (ESA), 16 U.S.C. § 1531 et seq.
Under section 7(a)(2) of the ESA, federal agencies are required to ensure that actions they authorize, fund, or carry out are not likely to jeopardize the continued existence of any listed, threatened, or endangered species, or destroy or adversely modify the designated critical habitat of such species. 16 U.S.C. § 1536(a)(2). The U.S. Fish and Wildlife Service and National Marine Fisheries Service have promulgated ESA implementing regulations at 50 C.F.R. part 402.
The CAA title V permit program requires the EPA to issue a permit specifically describing the permittee's existing pollution control obligations under the CAA. A title V permit does not generally create any new substantive requirements, but rather simply incorporates all existing CAA requirements, called "applicable requirements," into a single unified operating permit applicable to a particular facility. The title V permit the EPA is issuing to UGC does not authorize the construction of new emission units, or emission increases from existing units, nor does it otherwise authorize any physical modifications to the facility or its operations. The EPA has concluded that the permit appropriately incorporates all existing CAA requirements applicable to the facility. The EPA lacks discretion in this title V permitting decision to take action that could inure to the benefit of any listed species or their critical habitat. The EPA has concluded that issuance of this permit will have no effect on any listed species or their critical habitat. Accordingly, this permit action is consistent with the requirements of ESA section 7.
National Historic Preservation Act (NHPA), Public Law 89-665; 54 U.S.C. 300101 et seq.
The title V permit EPA is issuing to UGC does not authorize the construction of new emission units, or emission increases from existing units, nor does it otherwise authorize any physical modifications to the facility or its operations. The EPA has concluded that issuance of this permit will have no effect on any property under the NHPA of 1966 pursuant to section 106 of the NHPA, which requires federal agencies to consider the impact of their actions on historic properties.
Environmental Justice (EJ)
Executive Order 12898 directs federal agencies "to the greatest extent practicable and permitted by law," to "make achieving environmental justice part of its mission by identifying and addressing as appropriate, disproportionately high and adverse human health or environmental effects of its programs, policies, and activities on minority populations and low-income populations." Executive Order 14008 further directs federal agencies to "to address the disproportionately high and adverse human health, environmental, climate-related and other cumulative impacts on disadvantaged communities, as well as the accompanying economic challenges of such impacts." In addition, Executive Order 13985 calls on each federal agency to "pursue a comprehensive approach to advancing equity for all, including people of color and others who have been historically underserved, marginalized, and adversely affected by persistent poverty and inequality." Accordingly, advancing environmental justice and equity is one of EPA's highest priorities as set forth in the Agency's FY22-26 Strategic Plan.

The EPA defines "Environmental Justice" (EJ) to include the fair treatment and meaningful involvement of all people regardless of race, color, national origin, or income with respect to the development, implementation, and enforcement of environmental laws, regulations, and polices. The EPA's goal is to provide an opportunity for overburdened populations or communities to participate in the permitting process. "Overburdened" is used to describe the minority, low-income, tribal and indigenous populations or communities in the United States that potentially experience disproportionate environmental harms and risks due to exposures or cumulative impacts or greater vulnerability to environmental hazards.

As part of EPA's trust responsibility to the Ute Indian Tribe and the above noted Executive Orders, the EPA has kept the Tribe informed about this permit action by copying them on key communications such as the emailed application completeness determination and will provide a minimum 30-day public comment period, and opportunity for a public hearing if requested. The EPA does not routinely offer tribal consultation on Title V renewal permits for existing operating sources that do not incorporate any significant changes from the previously issued permit unless there is a request or known interest from the Tribe.

Permit Content

Draft permit sections 1  -  5

The draft permit contains all of the required elements for Part 71 permits, as specified in           40 C.F.R. § 71.5, including, but not limited to:

 Emissions limitations and standards, including those operational requirements and limitations that assure compliance with all applicable requirements at the time of permit issuance, as identified and discussed in this Statement of Basis;

 The permit duration, not to exceed 5 years;

 Monitoring and related recordkeeping and reporting requirements sufficient to assure and demonstrate compliance with all applicable requirements;

 A severability clause to ensure the continued validity of the various permit requirements in the event of a challenge to any portions of the permit;

 Specific provisions stating that: (a) any noncompliance constitutes a violations of the CAA and is grounds for enforcement action; (b) it is not a defense for the Permittee in an enforcement action that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the permit; (c) instructions for how the permit may be modified, revoked, reopened, reissued, or terminated for cause; (d) the permit does not convey and property rights or exclusive privilege; (e) and upon request, the Permittee shall furnish to the permitting authority copies of required records;

 A provision to ensure that the Permittee pays fees to the EPA consistent with the fee schedule approved in 40 C.F.R. § 71.9;

 A provision to ensure that the permit expires upon five years elapsing from the effective date; and

 An off-permit changes provision allowing changes that are not addressed or prohibited by the permit.

Changes Between the Previous Permit and Draft Permit

The permit has been reformatted using the EPA's new Part 71 permit and statement of basis standard templates. As a result, the permit condition numbering system has changed from the previous permit. For national consistency, the semi-annual reporting timeframe in the renewed permit (permit condition 45) is 30 days following the end of reporting period instead of 90 days listed in the previously issued permit.
Public Participation

Public Notice
As described in 40 C.F.R. § 71.11(a)(5), all Part 71 draft operating permits shall be publicly noticed and made available for public comment. The public notice of permit actions and public comment period is described in 40 C.F.R. § 71(d).

There will be a 30-day public comment period for actions pertaining to a draft permit. Notification will be given for this draft permit by mailing a copy of the notice to the permit applicant, the affected state, tribal and local air pollution control agencies, the city and county executives, and the state and federal land managers which have jurisdiction over the area where the source is located. A notification will be provided to all persons who have submitted a request to be included on the mailing list.

If you would like to be added to our mailing list to be informed of future actions on these or other CAA permits issued in Indian country, please send an email using the link for the Region 8 CAA public comment opportunities provided at https://www.epa.gov/caa-permitting/caa-permit-public-comment-opportunities-region-8, or send your name and address to the contact listed below:

U.S. Environmental Protection Agency, Region 8
Part 71 Permitting Lead
Air Permitting and Monitoring Branch (8ARD-PM)
1595 Wynkoop Street Denver, Colorado  80202-1129

Public notice will be provided at https://www.epa.gov/caa-permitting/caa-permit-public-comment-opportunities-region-8 giving opportunity for public comment on the draft permit and the opportunity to request a public hearing.

Opportunity to Comment
Members of the public will be given an opportunity to review a copy of the draft permit prepared by the EPA, the application, this Statement of Basis for the draft permit and all supporting materials for the draft permit. An electronic copy of the proposed permit and related documents may be viewed online at the website cited below. Information is also available by emailing or speaking with the following contact:

Contact: Lohitaksha (Lo.) Rao, Environmental Scientist, at<PHONE_NUMBER> or<EMAIL_ADDRESS>
Electronic copies of the draft permit, Statement of Basis and supporting permit record may also be accessed for review at:
https://www.epa.gov/caa-permitting/caa-permit-public-comment-opportunities-region-8.

Any interested person may submit written comments on the draft Part 71 operating permit during the public comment period to the Part 71 Permitting Lead at the address listed in Section A above, or by email using the instructions on the public comment opportunities web site address listed above or through https://www.regulations.gov (Docket I.D. #EPA-R08-OAR-2022-0276). All comments will be considered and answered by the EPA in making the final decision on the permit. The EPA keeps a record of the commenters and of the issues raised during the public participation process.

Anyone, including the applicant, who believes any condition of the draft permit is inappropriate should raise all reasonable ascertainable issues and submit all arguments supporting their position by the close of the public comment period. Any supporting materials submitted must be included in full and may not be incorporated by reference, unless the material has already been submitted as part of the administrative record in the same proceeding or consists of state or federal statutes and regulations, the EPA documents of general applicability or other generally available reference material.

The final permit will be a public record that can be obtained upon request. A statement of reasons for changes made to the draft permit and responses to comments received will be sent to all persons who comment on the draft permit. The final permit and response to comments document will also be accessible online at: https://www.epa.gov/caa-permitting/caa-permits-issued-epa-region-8. Anyone may request a copy of the final permit at any time by contacting the Tribal Air Permit Program at (800) 227 - 8917 or by sending an email to<EMAIL_ADDRESS>

Opportunity to Request a Hearing

A person may submit a written request for a public hearing to the Part 71 Permitting Lead, U.S. EPA Region 8, by stating the nature of the issues to be raised at the public hearing. Based on the number of hearing requests received, the EPA will hold a public hearing whenever it finds there is a significant degree of public interest in a draft operating permit. The EPA will provide public notice of the public hearing. If a public hearing is held, any person may submit oral or written statements and data concerning the draft permit.

Appeal of Permits

Within 30 days after the issuance of a final permit decision, any person who filed comments on the draft permit or participated in the public hearing may petition to the Environmental Appeals Board (EAB) to review any condition of the permit decision. Any person who failed to file comments or participate in the public hearing may petition for administrative review, only if the changes from the draft to the final permit decision or other new grounds were not reasonably foreseeable during the public comment period. The 30-day period to appeal a permit begins with the EPA's service of the notice of the final permit decision.

The petition to appeal a permit must include a statement of the reasons supporting the review, a demonstration that any issues were raised during the public comment period, a demonstration that it was impracticable to raise the objections within the public comment period, or that the grounds for such objections arose after such a period. When appropriate, the petition may include a showing that the condition in question is based on a finding of fact or conclusion of law which is clearly erroneous; or, an exercise of discretion, or an important policy consideration that the EAB should review.

The EAB will issue an order either granting or denying the petition for review, within a reasonable time following the filing of the petition. Public notice of the grant of review will establish a briefing schedule for the appeal and state that any interested person may file an amicus brief. Notice of denial of review will be sent only to the permit applicant and to the person requesting the review. To the extent review is denied, the conditions of the final permit decision become final agency action.

A motion to reconsider a final order shall be filed within ten days after the service of the final order. Every motion must set forth the matters claimed to have been erroneously decided and the nature of the alleged errors. Motions for reconsideration shall be directed to the Administrator rather than the EAB. A motion for reconsideration shall not stay the effective date of the final order unless it is specifically ordered by the EAB.

Petition to Reopen a Permit for Cause

Any interested person may petition the EPA to reopen a permit for cause, and the EPA may commence a permit reopening on its own initiative.

The EPA will only revise, revoke and reissue, or terminate a permit for the reasons specified in             40 C.F.R. § 71.7(f) or 71.6(a)(6)(i). All requests must be in writing and must contain facts or reasons supporting the request. If the EPA decides the request is not justified, it will send the requester a brief written response giving a reason for the decision. Denial of these requests is not subject to public notice, comment, or hearings. Denials can be informally appealed to the EAB by a letter briefly setting forth the relevant facts.
Abbreviations and Acronyms

ASTM  		American Society for Testing and Materials
CAA  			Clean Air Act [42 U.S.C. § 7401, et seq.]
CEDRI		Compliance and Emission Reporting Data Interface
C.F.R.			Code of Federal Regulations
CH2O			Formaldehyde
CO			Carbon Monoxide
EPA  			U.S. Environmental Protection Agency, Region 8
EU  			Emission Unit
Facility  		River Bend Dehydration Site located Latitude 39.94986, Longitude 109.77469
gal  			gallon
g  			grams
HAP  			Hazardous Air Pollutant
hr  			hour
I.D.         		Identification Number
kg  			kilogram
lb  			pound
MACT  		Maximum Achievable Control Technology
Mfd			Manufactured
Mg  			Megagram
MMBtu  		Million British Thermal Units
NESHAP  		National Emission Standards for Hazardous Air Pollutants
NOx  			Nitrogen Oxides
NSPS  			New Source Performance Standards
NSR  			New Source Review
Operator	                 Utah Gas Corporation
Permittee	                 Utah Gas Corporation
PM  			Particulate Matter
PM10  			Particulate Matter less than 10 microns in diameter
ppm  			parts per million
PSD  			Prevention of Significant Deterioration
PTE   			Potential to Emit
SO2  			Sulfur Dioxide
VOC  			Volatile Organic Compounds


[Federal Register Volume 78, Number 28 (Monday, February 11, 2013)]
[Proposed Rules]
[Pages 9651-9654]
[FR Doc No: 2013-02964]

-----------------------------------------------------------------------

ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 52

[EPA-R10-OAR-2012-0494: FRL-9778-7]

Approval and Promulgation of Implementation Plans; Oregon: Heat
Smart Program and Enforcement Procedures

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule.

-----------------------------------------------------------------------

SUMMARY: The EPA is proposing to approve multiple revisions to Oregon's
State Implementation Plan (SIP) submitted to the EPA by the Oregon
Department of Environmental Quality (ODEQ) on October 5, 2011, June 8,
2012, and November 28, 2012. The October 5, 2011 submission contains
revisions to the Heat Smart program and to the enforcement procedures
and civil penalties in Oregon Administrative Rules (OAR) Chapter 340,
Division 12 (OAR 340-12). The June 8, 2012 submission contains
additional revisions to the Heat Smart program, along with minor
revisions and clarifications to general air pollution definitions (OAR
340-200), rules for stationary source notification requirements (OAR
340-210), and requirements for fuel burning (OAR 340-228). The November
28, 2012 submission contains revisions to approve the inclusion of
expedited enforcement offers and updated penalty classifications and
criteria (OAR 340-012).

DATES: Comments must be received on or before March 13, 2013.

ADDRESSES: Submit your comments, identified by Docket ID No. EPA-R10-
OAR-2012-0494, by one of the following methods:
    A. www.regulations.gov. Follow the on-line instructions for
submitting comments.
    B. Mail: Justin A. Spenillo, EPA, Office of Air, Waste, and Toxics,
AWT-107, 1200 Sixth Avenue, Suite 900, Seattle, Washington 98101.
    C. Email<EMAIL_ADDRESS>    D. Hand Delivery: EPA, Region 10 Mailroom, 9th Floor, 1200 Sixth
Avenue, Seattle, Washington 98101. Attention: Justin A. Spenillo,
Office of Air Waste, and Toxics, AWT-107. Such deliveries are only
accepted during normal hours of operation, and special arrangements
should be made for deliveries of boxed information.
    Instructions: Direct your comments to Docket ID No. EPA-R10-OAR-
2012-0494. The EPA's policy is that all comments received will be
included in the public docket without change and may be made available
online at www.regulations.gov, including any personal information
provided, unless the comment includes information claimed to be
Confidential Business Information (CBI) or other information that is
restricted by statute from disclosure. Do not submit information that
you consider to be CBI or otherwise protected through
www.regulations.gov or email. The www.regulations.gov Web site is an
``anonymous access'' system, which means the EPA will not know your
identity or contact information unless you provide it in the body of
your comment. If you send an email comment directly to the EPA without
going through www.regulations.gov your email address will be
automatically captured and included as part of the comment that is
placed in the public docket and made available on the Internet. If you
submit an electronic comment, the EPA recommends that you include your
name and other contact information in the body of your comment and with
any disk or CD-ROM you submit. If the EPA cannot read your comment due
to technical difficulties and cannot contact you for clarification, the
EPA may not be able to consider your comment. Electronic files should
avoid the use of special characters, any form of encryption, and be
free of any defects or viruses.
    Docket: All documents in the electronic docket are listed in the
www.regulations.gov index. Although listed in the index, some
information is not publicly available, i.e., CBI or other information
that is restricted by statute from disclosure. Certain other material,
such as copyrighted material, is not placed on the Internet and will be
publicly available only in hard copy form. Publicly available docket
materials are available either electronically at www.regulations.gov or
in hard copy during normal business hours at the Office of Air, Waste
and Toxics, EPA Region 10, 1200 Sixth Avenue, Seattle, Washington
98101.

FOR FURTHER INFORMATION CONTACT: Justin A. Spenillo,<PHONE_NUMBER>; or
by email at spenillo.justin<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:

Table of Contents

I. This Action
II. Why are we proposing to approve these revisions?
    A. The EPA's Review of OAR Chapter 340, Division 262 Heat Smart
Program for Residential Woodstoves and Other Solid Fuel Heating
Devices (October 5, 2011 and June 8, 2012 Submittals)
    B. The EPA's Review of OAR Chapter 340, Division 12 Rules
(October 5, 2011 and November 28, 2012 Submittals)
    C. The EPA's Review of OAR Chapter 340, Divisions 200, 210, and
228 Rules (June 8, 2012 Submittal)
    D. The EPA's Review of OAR<PHONE_NUMBER> (October 5, 2011, June
8, 2012, and November 28, 2012 Submittals)
III. Summary of Action
IV. Statutory and Executive Orders Review

I. This Action

    Title I of the CAA, as amended by Congress in 1990, specifies the
general requirements for states to submit SIPs to attain and maintain
the National Ambient Air Quality Standards (NAAQS) and the EPA's
actions regarding approval of those SIPs. In this action, we are
proposing to approve and incorporate by reference (IBR) revisions

to the portions of Oregon's SIP relating to the Heat Smart Program
found at OAR 340-262 and submitted by ODEQ on October 5, 2011 and June
8, 2012.
    The EPA is also proposing to approve but not IBR revisions to
enforcement provisions in OAR 340-012, submitted by ODEQ on October 5,
2011 and November 28, 2012. In addition, the EPA proposes to approve
the remaining revisions to OAR 340-012 only to the extent they relate
to enforcement of requirements contained in the Oregon SIP.
    The EPA proposes to approve revisions to OAR 340-200 (except OAR
340-200-0040), OAR 340-210 and OAR 340-228, as they relate to general
definitions, stationary source notification requirements, and fuel
requirements in the Oregon SIP. These revisions were submitted by ODEQ
on June 8, 2012.
    Each of the above-described submittals (October 5, 2011, June 8,
2012, and November 28, 2012) contains an amendment to OAR<PHONE_NUMBER>,
which describes the State's procedures for adopting its Clean Air Act
Implementation Plan and references all of the state air regulations
that have been adopted by the Environmental Quality Commission (EQC)
for approval into the SIP (as a matter of state law), whether or not
they have been submitted or approved by the EPA. We are proposing no
action on the revisions to OAR<PHONE_NUMBER> in each of these submittals
because it is unnecessary to take action on a provision addressing the
State's SIP adoption procedures and because the Federally-approved SIP
consists only of regulations and other requirements that have been
submitted by ODEQ and approved by the EPA.

II. Why are we proposing to approve these revisions?

    We are proposing to approve the SIP revisions submitted by ODEQ on
October 5, 2011, June 8, 2012, and November 28, 2012 (except for OAR
340-200-0040) because they serve to clarify and strengthen the State's
existing SIP and are consistent with the CAA requirements. A more
detailed explanation of the basis for our approval is provided below
and in the materials included in the docket.

A. The EPA's Review of OAR Chapter 340, Division 262 Heat Smart Program
for Residential Woodstoves and Other Solid Fuel Heating Devices
(October 5, 2011 and June 8, 2012 Submittals)

    OAR 340-262 was last approved by the EPA on January 22, 2003 (68 FR
2891). The Federally-approved woodheating rules previously codified at
OAR 340-262 have been reorganized and strengthened within the same
division and renamed as the Heat Smart Program for Residential
Woodstoves and Other Solid Fuel Heating Devices. The Heat Smart program
requires the removal of uncertified woodstoves and most other
uncertified solid fuel heating devices upon the sale of a home. The
revisions included in ODEQ's October 5, 2011 and June 8, 2012
submittals provide for: establishing the Heat Smart program as a
statewide program as opposed to being a contingency measure only
applicable to non-attainment areas in Oregon, streamlining and
reorganizing the existing woodheating rules, and additions to the rules
that strengthen the division and contribute to maintenance of the
NAAQS. Table 1 below outlines the reorganization of OAR 340-262.

                 Table 1--Reorganization of OAR 340-262
------------------------------------------------------------------------
                                  Prior
           Rule name               rule               New rule
------------------------------------------------------------------------
Purpose.......................  -0010      -0400
Definitions...................  -0020      -0450
Woodstove Sales--Requirements   -0030      -0600
 for Sale of Woodstoves.
Exemptions....................  -0040      -0600, -0700, -0800
Civil Penalties...............  -0050      -0800
Woodstove Certification         -0100      -0500
 Program--Applicability.
Emissions Performance           -0110      -0500
 Standards and Certification.
General Certification           -0120      -0500
 Procedures.
Labeling Requirements.........  -0130      -0600
Woodburning Curtailment--       -0200      -0800 (1)
 Applicability.
Determination of Air            -0210      -0800 (3)
 Stagnation Conditions.
Prohibition of Woodburning      -0220      -0800 (4)
 During Periods of Air
 Stagnation.
Public Information Program....  -0230      -0800 (5)
Enforcement...................  -0240      -0800 (6-8)
Suspension and Department       -0250      -0800 (9)
 Program.
Woodstove Removal Contingency   -0300      -0700
 Program--Applicability.
Removal and Destruction of      -0310      -0700
 Uncertified Stove Upon Sale
 of Home.
Home Seller's Responsibility    -0320      -0700
 to Verify Stove Destruction.
Home Seller's Responsibility    -0330      -0700
 to Disclose.
Materials Prohibited from       New        -0900
 Burning.
------------------------------------------------------------------------

The expansion of the Heat Smart program to a statewide program makes it
applicable to a larger geographic area and with broader criteria, and
enhances protection of air quality by accelerating the replacement of
uncertified woodstoves. This revision strengthens the SIP by increasing
the applicability and scope of the Heat Smart program which will result
in the removal of more uncertified woodstoves and other uncertified
solid fuel heating devices, and is therefore more protective of the
NAAQS.

    In addition to the reorganization of OAR 340-262 and the expansion
of the Heat Smart program statewide, Oregon submitted for approval a
number of additions, clarifications, and streamlining revisions. Oregon
requests approval to add prohibitions limiting the types of materials
that can be burned in a solid fuel device. The inclusion of such
limitations strengthens the SIP by reducing the potential emission of
criteria pollutants from the burning of inappropriate material. Oregon
also proposes to expand the applicability of the rules from woodstoves/
woodheaters to include solid fuel burning devices. The October 5, 2011
submittal requests approval to include a new definition for solid fuel
burning devices that includes

woodstoves and other devices that burn wood, coal, or other nongaseous
or nonliquid fuels. The June 8, 2012 submittal refines the definition
to maintain the residential focus of the rule by not including small
scale heating devices used for commercial, industrial, and
institutional facilities. The new definition of solid fuel burning
devices is more stringent because it covers residential heating devices
that use wood, coal, or other non-gaseous or non-liquid fuels in
addition to the residential woodheating devices covered under the prior
definition.
    Based on the EPA's review and analysis of OAR 340-262, the EPA is
proposing to approve the above-described SIP strengthening revisions as
meeting the requirements of section 110 of the CAA. In addition, the
EPA proposes to remove from the SIP the regulations previously codified
at OAR<PHONE_NUMBER> to OAR<PHONE_NUMBER> because the citations for these
regulations have been renumbered as shown in Table 1.

B. The EPA's Review of OAR Chapter 340, Division 12 Rules (October 5,
2011 and November 28, 2012 Submittals)

    The October 5, 2011 submittal included revisions to OAR 340-012-
0054 and<PHONE_NUMBER>. These revisions strengthen enforcement by
including as Class I and II violations the restrictions on burning
certain materials in solid fuel devices contained in OAR<PHONE_NUMBER>,
and by updating the related penalty matrix. Oregon is also requesting
one revision to remove as a Class III violation the failure to display
a certified woodstove temporary label. The removal of this violation as
a Class III violation will not interfere with attainment and
maintenance of the NAAQS.
    The November 28, 2012 submittal includes one substantive revision
and minor typographical and renumbering revisions. The substantive
revision was the addition of expedited enforcement offers and
associated criteria at OAR<PHONE_NUMBER>,<PHONE_NUMBER>, and 340-012-
0170. An expedited enforcement offer is a written offer from ODEQ to
settle alleged violations using expedited procedures. The purpose of
expedited enforcement offers is to promote compliance and enforcement
through faster, informal resolution of alleged violations. The minor
typographical and renumbering revisions address OAR<PHONE_NUMBER>.
    The EPA has reviewed the revisions described above and finds that
they provide ODEQ with adequate authority for enforcing the SIP as
required by Section 110 of the CAA and 40 CFR 51.230(b). The EPA is
therefore proposing to approve the revisions to OAR 340-012 subject to
the qualifications and in the manner discussed below.
    The EPA's authority to approve SIP revisions extends to provisions
related to attainment and maintenance of the NAAQS and carrying out
other specific requirements of Section 110 of the CAA. In addition, EPA
is approving the remaining sections in OAR 340-012 only to the extent
they relate to enforcement of requirements contained in the Oregon SIP.
    Although the EPA is approving the regulations in OAR 340-012 in the
manner discussed above, the EPA is not incorporating these rules by
reference into the Code of Federal Regulations because the EPA relies
on its own independent enforcement procedures and penalty provisions in
bringing enforcement actions and assessing penalties under the CAA.
    The EPA also notes that Oregon Revised Statute (ORS) 468.126
prohibits ODEQ from imposing a penalty for violation of an air, water
or solid waste permit unless the source has been provided five days
advanced written notice of the violation and has not come into
compliance or submitted a compliance schedule within that five-day
period. By its terms, this statutory provision does not apply to
Oregon's Title V program or to any program if application of the notice
provision would disqualify the program from Federal delegation. Oregon
has previously confirmed that, because application of the notice
provision would preclude the EPA approval of the Oregon SIP, no advance
notice is required for violation of SIP requirements.

C. The EPA's Review of OAR Chapter 340, Divisions 200, 210, and 228
Rules (June 8, 2012 Submittal)

    The June 8, 2012 submission includes revisions to OAR 340,
Divisions 200, 210, and 228, which were last subject to the EPA
approval on January 22, 2003 (68 FR 2891). OAR 340-200 includes the
rules for General Air Pollution Procedures and Definitions, OAR 340-210
includes the rules for Stationary Source Notification Requirements, and
OAR 340-228 includes the rules for Requirements for Fuel Burning
Equipment and Fuel Sulfur.
    Revisions to OAR<PHONE_NUMBER>, General Air Quality Definitions,
include minor typographical corrections, inclusion of a definition of
``form,'' and subsequent renumbering.
    Revisions to OAR 340-210, Stationary Source Notification
Requirements, include changes to OAR<PHONE_NUMBER>,<PHONE_NUMBER>, 340-
210-0120, and<PHONE_NUMBER>. The revisions to OAR<PHONE_NUMBER> expand
upon and clarify the applicable sources, personnel, and criteria
necessary for a source to register with ODEQ in lieu of obtaining a
permit. The revision to OAR<PHONE_NUMBER> also includes updated fee
information and clarifies the registration requirements applicable to
sources subject to a federal New Source Performance Standards (NSPS)
and National Emission Standards for Hazardous Air Pollutants (NESHAPs).
Revisions to OAR<PHONE_NUMBER> and<PHONE_NUMBER> expand and clarify the
registration criteria and requirements to maintain registration.
Revisions to OAR<PHONE_NUMBER>, Approval to Operate, clarify that
compliance with existing standards, testing and monitoring
requirements, and registration are still required and applicable. These
revisions are more detailed and stringent than the previously approved
provisions and are improvements to the rule.
    Revisions to OAR 340-228, Requirements for Fuel Burning Equipment
and Fuel Sulfur Content, include changes to OAR<PHONE_NUMBER>, 340-228-
0200, and<PHONE_NUMBER>. These revisions include a cross reference to
the revised OAR 340-262 and clarify source applicability dates.
    Based on the EPA's review and analysis of the revisions to OAR 340-
200, 340-210, and 340-228, the EPA is proposing to approve the
revisions because they meet the requirements of section 110 of the CAA
and will not interfere with attainment or maintenance of the NAAQS.

D. The EPA's Review of OAR<PHONE_NUMBER> (October 5, 2011, June 8, 2012,
and November 28, 2012 Submittals)

    On October 5, 2011, June 8, 2012, and November 28, 2012, Oregon
submitted for SIP approval amendments to OAR<PHONE_NUMBER>. The EPA is
proposing no action on these amendments because it is unnecessary to
take action on provisions addressing the State's SIP adoption
procedures and incorporating by reference all of the revisions adopted
by the State for approval into the SIP (as a matter of state law).

III. Summary of Action

    The EPA is proposing to approve amendments to OAR Chapter 340,
Divisions 12, 200, 210, 228 and 262 because they are consistent with
CAA requirements. We are also proposing to take no action to approve
amendments to OAR<PHONE_NUMBER> submitted on October 5, 2011, June 8,
2012, and November 28, 2012.

IV. Statutory and Executive Order Reviews

    Under the CAA, the Administrator is required to approve a SIP
submission that complies with the provisions of the Act and applicable
Federal regulations. 42 U.S.C. 7410(k); 40 CFR 52.02(a). Thus, in
reviewing SIP submissions, EPA's role is to approve state choices,
provided that they meet the criteria of the CAA. Accordingly, this
action merely approves state law as meeting Federal requirements and
does not impose additional requirements beyond those imposed by state
law. For that reason, this action:
     Is not a ``significant regulatory action'' subject to
review by the Office of Management and Budget under Executive Order
12866 (58 FR 51735, October 4, 1993);
     Does not impose an information collection burden under the
provisions of the Paperwork Reduction Act (44 U.S.C. 3501 et seq.);
     Is certified as not having a significant economic impact
on a substantial number of small entities under the Regulatory
Flexibility Act (5 U.S.C. 601 et seq.);
     Does not contain any unfunded mandate or significantly or
uniquely affect small governments, as described in the Unfunded
Mandates Reform Act of 1995 (Pub. L. 104-4);
     Does not have Federalism implications as specified in
Executive Order 13132 (64 FR 43255, August 10, 1999);
     Is not an economically significant regulatory action based
on health or safety risks subject to Executive Order 13045 (62 FR
19885, April 23, 1997);
     Is not a significant regulatory action subject to
Executive Order 13211 (66 FR 28355, May 22, 2001);
     Is not subject to requirements of Section 12(d) of the
National Technology Transfer and Advancement Act of 1995 (15 U.S.C. 272
note) because application of those requirements would be inconsistent
with the Clean Air Act; and
     Does not provide EPA with the discretionary authority to
address, as appropriate, disproportionate human health or environmental
effects, using practicable and legally permissible methods, under
Executive Order 12898 (59 FR 7629, February 16, 1994).
    In addition, this rule does not have tribal implications as
specified by Executive Order 13175 (65 FR 67249, November 9, 2000),
because the SIP is not approved to apply in Indian country located in
the state, and it will not impose substantial direct costs on tribal
governments or preempt tribal law.

List of Subjects in 40 CFR Part 52

    Environmental protection, Air pollution control, Particulate
matter.

    Dated: January 31, 2013.
Dennis J. McLerran,
Regional Administrator, Region 10.
[FR Doc. 2013-02964 Filed 2-8-13; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register Volume 88, Number 31 (Wednesday, February 15, 2023)]
[Notices]
[Pages 9929-9930]
[FR Doc No: 2023-03230]

-----------------------------------------------------------------------

SECURITIES AND EXCHANGE COMMISSION

[SEC File No. 270-797, OMB Control No. 3235-0748]

Proposed Collection; Comment Request: Extension; ``Ombudsman
Matter Management System Submission Form''

Upon Written Request Copies Available From: Securities and Exchange
Commission, Office of the Investor Advocate, Washington, DC 20549-3720

    Notice is hereby given pursuant to the Paperwork Reduction Act of
1995 (44 U.S.C. 3501 et seq.) that the Securities and Exchange
Commission (``Commission'') is soliciting comments on the collection of
information summarized below. The Commission plans to submit this
existing collection of information to the Office of Management and
Budget (``OMB'') for extension and approval.
    Each year the Commission's Office of the Investor Advocate, Office
of the Ombudsman (``Ombudsman'') receives over a thousand contacts from
investors who have complaints or questions about the SEC or any of the
self-regulatory organizations that it oversees. To make it easier for
the public to contact the Ombudsman, the Ombudsman (``Ombudsman'')
created an electronic form (Ombudsman Matter Management System
Submission Form) that provides drop down options to choose from in
order to categorize the investor's complaint or question, and may also
provide the investor with automated information about their issue. The
Ombudsman Matter Management System (OMMS) Submission Form asks
investors to provide information concerning, among other things, their
names, how they can be reached, the names of the individuals or
entities involved, the nature of their complaint or tip, what documents
they can provide, and what, if any, actions they have taken. Use of the
Ombudsman Matter Management System Submission Form is voluntary. Absent
the forms, the public still has several ways to contact the Ombudsman,
including telephone, letters, and email. Investors can access the
Ombudsman Matter Management System Submission Form through the
Ombudsman web page at the web address https://www.sec.gov/ombudsman or
directly at the web address https://omms.sec.gov.
    The dual purpose of the Ombudsman Matter Management System
Submission Form is to make it easier for the public to contact the
agency with complaints,

questions, tips, or other feedback and to streamline the workflow of
Ombudsman staff that record, process, and respond to investor contacts.
Investors who submit complaints, ask questions, or provide tips do so
voluntarily. Although the Ombudsman Matter Management System Submission
Form provides a structured format for incoming investor correspondence,
the Commission does not require that investors use any particular form
or format when contacting the Ombudsman. Investors who choose not to
use the Ombudsman Matter Management System Submission Form will receive
the same level of service as those who do.
    The Ombudsman receives approximately 1,500 contacts each year
through the Ombudsman Matter Management System Submission Form. The
Ombudsman uses the information that investors supply on the Ombudsman
Matter Management System Submission Form to review and process the
contact (which may, in turn, involve responding to questions,
processing complaints, or, as appropriate, referring matters to
enforcement or examinations for potential investigations), to maintain
a record of contacts, to track the volume of investor complaints, and
to analyze trends.
    The staff of the Commission estimates that the total reporting
burden for using the Ombudsman Matter Management System Submission Form
is 750 hours. The calculation of this estimate depends on the number of
investors who use the forms each year and the estimated time it takes
to complete the forms: 1,500 respondents x 30 minutes = 750 burden
hours. Members of the public should be aware that an agency may not
conduct or sponsor, and a person is not required to respond to, a
collection of information unless a currently valid OMB control number
is displayed. Background documentation for this information collection
may be viewed at the following link, http://www.reginfo.gov. General
comments regarding the above information submitted within 60 days of
this publication will be considered by April 17, 2023 and should be
directed to the following persons: (i) Desk Officer for the Securities
and Exchange Commission, Office of Information and Regulatory Affairs,
Office of Management and Budget, Room 10102, New Executive Office
Building, Washington, DC 20503 or send an email to:
[email protected]; and (ii) David Bottom, Director/Chief
Information Officer, Securities and Exchange Commission, c/o John R.
Pezzullo, 100 F St NE, Washington, DC 20549; or send an email to:
[email protected].

    Dated: February 10, 2023.
Sherry R. Haywood,
Assistant Secretary.
[FR Doc. 2023-03230 Filed 2-14-23; 8:45 am]
BILLING CODE 8011-01-P


[Federal Register: June 25, 2010 (Volume 75, Number 122)]
[Notices]
[Page 36463-36464]
[DOCID:fr25jn10-110]

=======================================================================
-----------------------------------------------------------------------

DEPARTMENT OF TRANSPORTATION

Office of the Secretary

[DOT-OST-2010-0025]

Notice of Request for Renewal of a Previously Approved Collection

AGENCY: Office of the Secretary, DOT.

ACTION: Notice and request for comments.

-----------------------------------------------------------------------

SUMMARY: In accordance with the Paperwork Reduction Act of 1995 (44
U.S.C. chapter 35, as amended) this notice announces that the
Information Collection Request (ICR) abstracted below which will be
forwarded to the Office of Management and Budget (OMB) for renewal. The
ICR describes the nature of the information collection and its expected
burden. The Federal Register notice with a 60-day comment period
soliciting comments on the following collection of information was
published on February 2, 2010 (75 FR 5369). No comments were received.

DATES: Comments on this notice must be received by July 26, 2010 and
sent to the attention of the DOT/OST Desk Officer, Office of
Information and Regulatory Affairs, Office of Management and Budget,
Docket Library, Room 10102, 725 17th Street, NW., Washington, DC 20503
or<EMAIL_ADDRESS>(e-mail).

FOR FURTHER INFORMATION CONTACT: Mr. Robert C. Ashby, Office of the
Secretary, Office of Assistant General Counsel for Regulation and
Enforcement, Department of Transportation, 400 Seventh St., SW.,
Washington, DC 20590,<PHONE_NUMBER> (voice)<PHONE_NUMBER> (fax) or at
<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:
    Title: Report of DBE Awards and Commitments.
    OMB Control Number: 2105-0510.

    Affected Public: DOT financially-assisted State and local
transportation agencies.
    Frequency of response: once/twice a year.
    Estimated Total Burden on Respondents: 1,311,000.
    Comments are invited on: (a) Whether the proposed collection of
information is necessary for the proper performance of the functions of
the Department, including whether the information will have practical
utility; (b) the accuracy of the Department's estimate of the burden of
the proposed information collection; (c) ways to enhance the quality,
utility and clarity of the information to be collected; and (d) ways to
minimize the burden of the collection of information on respondents,
including the use of automated collection techniques or other forms of
information technology. All responses to this notice will be summarized
and included in the request for OMB approval. All comments will also
become a matter of public record.

    Issued in Washington, DC, on June 21, 2010.
Robert C. Ashby,
Deputy Assistant General Counsel for Regulation and Enforcement.
[FR Doc. 2010-15419 Filed 6-24-10; 8:45 am]
BILLING CODE 4910-9X-P


Comment Info: =================

General Comment:A 75 day period to review the proposed regulations is insufficient. I request that the review period be extended to 180 days.


[Federal Register Volume 75, Number 250 (Thursday, December 30, 2010)]
[Notices]
[Pages 82378-82379]
[FR Doc No: 2010-32836]

=======================================================================
-----------------------------------------------------------------------

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. CP11-52-000]

Tennessee Gas Pipeline Company; Notice of Application

December 22, 2010.
    Take notice that on December 15, 2010, Tennessee Gas Pipeline
Company (Tennessee), 1001 Louisiana Street, Houston, Texas 77002, filed
in Docket No. CP11-52-000 an application pursuant to section 7(b) of
the Natural Gas Act (NGA) and the Commission Regulations, for
authorization to abandon by sale to Tauber Pipeline L.L.C. (Tauber)
three supply laterals and related facilities located in South Texas,
all as more fully set forth in the application which is on file with
the Commission and open to public inspection. The filing may also be
viewed on the Web at http://www.ferc.gov using the ``eLibrary'' link.
Enter the docket number excluding the last three digits in the docket
number field to access the document. For assistance, please contact
FERC Online Support at<EMAIL_ADDRESS>or toll free at (866)
208-3676, or TTY, contact<PHONE_NUMBER>.
    Any questions concerning this application may be directed to James
D. Johnston, Associate General Counsel, Tennessee Gas Pipeline Company,
1001 Louisiana Street, Houston, Texas 77002 at<PHONE_NUMBER> or by e-
mail at<EMAIL_ADDRESS>    Specifically, Tennessee filed an application requesting approval
for abandonment by sale to Tauber of three supply laterals: Tennessee's
Line 5A-100, approximately 5.8 miles of 10-inch pipeline, Line No. 5A-
200, approximately 32.2 miles of 12-inch pipeline, and Line No. 5A-300,
approximately 6.2 miles of 6-inch pipeline.
    Pursuant to section 157.9 of the Commission's rules, 18 CFR 157.9,
within 90 days of this Notice the Commission staff will either complete
its environmental assessment (EA) and place it into the Commission's
public record (eLibrary) for this proceeding; or

issue a Notice of Schedule for Environmental Review. If a Notice of
Schedule for Environmental Review is issued, it will indicate, among
other milestones, the anticipated date for the Commission staff's
issuance of the final environmental impact statement (FEIS) or EA for
this proposal. The filing of the EA in the Commission's public record
for this proceeding or the issuance of a Notice of Schedule for
Environmental Review will serve to notify Federal and State agencies of
the timing for the completion of all necessary reviews, and the
subsequent need to complete all Federal authorizations within 90 days
of the date of issuance of the Commission staff's FEIS or EA.
    There are two ways to become involved in the Commission's review of
this project. First, any person wishing to obtain legal status by
becoming a party to the proceedings for this project should, on or
before the comment date stated below, file with the Federal Energy
Regulatory Commission, 888 First Street, NE., Washington, DC 20426, a
motion to intervene in accordance with the requirements of the
Commission's Rules of Practice and Procedure (18 CFR 385.214 or
385.211) and the Regulations under the NGA (18 CFR 157.10). A person
obtaining party status will be placed on the service list maintained by
the Secretary of the Commission and will receive copies of all
documents filed by the applicant and by all other parties. A party must
submit an original and 7 copies of filings made with the Commission and
must mail a copy to the applicant and to every other party in the
proceeding. Only parties to the proceeding can ask for court review of
Commission orders in the proceeding.
    However, a person does not have to intervene in order to have
comments considered. The second way to participate is by filing with
the Secretary of the Commission, as soon as possible, an original and
two copies of comments in support of or in opposition to this project.
The Commission will consider these comments in determining the
appropriate action to be taken, but the filing of a comment alone will
not serve to make the filer a party to the proceeding. The Commission's
rules require that persons filing comments in opposition to the project
provide copies of their protests only to the party or parties directly
involved in the protest.
    Persons who wish to comment only on the environmental review of
this project should submit an original and two copies of their comments
to the Secretary of the Commission. Environmental commentors will be
placed on the Commission's environmental mailing list, will receive
copies of the environmental documents, and will be notified of meetings
associated with the Commission's environmental review process.
Environmental commentors will not be required to serve copies of filed
documents on all other parties. However, the non-party commentors will
not receive copies of all documents filed by other parties or issued by
the Commission (except for the mailing of environmental documents
issued by the Commission) and will not have the right to seek court
review of the Commission's final order.
    The Commission strongly encourages electronic filings of comments,
protests and interventions in lieu of paper using the ``eFiling'' link
at http://www.ferc.gov. Persons unable to file electronically should
submit an original and 14 copies of the protest or intervention to the
Federal Energy Regulatory Commission, 888 First Street, NE.,
Washington, DC 20426.
    This filing is accessible on-line at http://www.ferc.gov, using the
``eLibrary'' link and is available for review in the Commission's
Public Reference Room in Washington, DC. There is an ``eSubscription''
link on the Web site that enables subscribers to receive e-mail
notification when a document is added to a subscribed docket(s). For
assistance with any FERC Online service, please e-mail
<EMAIL_ADDRESS>or call<PHONE_NUMBER> (toll free). For
TTY, call<PHONE_NUMBER>.
    Comment Date: January 12, 2011.

Kimberly D. Bose,
Secretary.
[FR Doc. 2010-32836 Filed 12-29-10; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 82, Number 94 (Wednesday, May 17, 2017)]
[Notices]
[Page 22656]
[FR Doc No: 2017-09959]

-----------------------------------------------------------------------

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Combined Notice of Filings

    Take notice that the Commission has received the following Natural
Gas Pipeline Rate and Refund Report filings:

Filings Instituting Proceedings

    Docket Number: PR17-42-000.
    Applicants: Columbia Gas of Ohio, Inc.
    Description: Tariff filing per 284.123(b),(e)/: COH SOC Rate
effective 5-1-2017; Filing Type: 980.
    Filed Date: 5/8/17.
    Accession Number:<PHONE_NUMBER>39.
    Comments/Protests Due: 5 p.m. ET 5/30/17.

    Docket Numbers: RP17-739-000.
    Applicants: Iroquois Gas Transmission System, L.P.
    Description: Iroquois Gas Transmission System, L.P. submits tariff
filing per 154.204: 05/08/17 Negotiated Rates--Consolidated Edison
Energy Inc. (HUB) 2275-89 to be effective 5/10/2017.
    Filed Date: 05/08/2017.
    Accession Number: 20170508-5084.
    Comment Date: 5:00 p.m. Eastern Time on Monday, May 22, 2017.

    Docket Numbers: RP17-740-000.
    Applicants: ARM Energy Management,Salt Creek Midstream, LLC.
    Description: Joint Petition of ARM Energy Management, LLC, et al.
for Temporary Waiver of Commission Capacity Release Regulations and
Related Tariff Provisions, and Request for Expedited Action.
    Filed Date: 05/08/2017.
    Accession Number: 20170508-5206.
    Comment Date: 5:00 p.m. Eastern Time on Monday, May 15, 2017.

    The filings are accessible in the Commission's eLibrary system by
clicking on the links or querying the docket number.
    Any person desiring to intervene or protest in any of the above
proceedings must file in accordance with Rules 211 and 214 of the
Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00
p.m. Eastern time on the specified comment date. Protests may be
considered, but intervention is necessary to become a party to the
proceeding.
    eFiling is encouraged. More detailed information relating to filing
requirements, interventions, protests, service, and qualifying
facilities filings can be found at: http://www.ferc.gov/docs-filing/efiling/filing-req.pdf. For other information, call<PHONE_NUMBER>
(toll free). For TTY, call<PHONE_NUMBER>.

    Dated: May 9, 2017.
Kimberly D. Bose,
 Secretary.
[FR Doc. 2017-09959 Filed 5-16-17; 8:45 am]
BILLING CODE 6717-01-P