### Mr. Karl Brooks Page Two

The commission has full legal authority to develop rules pursuant to Section 643.050 of the Missouri
Air Conservation Law. The state followed all applicable administrative procedures in proposing and adopting the rule action(s).

Enclosed are the required SIP submittal elements for determination of plan completeness per 40 CFR
Part 51, Appendix V.

Compliant with the April 6, 2011 SIP regional consistency memo, an exact duplicate of this submittal
is also being provided as an electronic attachment in an email to the Region VII Missouri
coordinator. A searchable pdf version of the rule is available on the Code of State Regulations
website at http://www.sos.mo.gov/adrules/csr/currentJI0csr/lOcl0-5.pdf.

Thank you for your attention to this matter. If you have any questions regarding this submittal, please contact Wendy Vit, with the Department's Air Pollution Control Program at P.O. Box 176,
Jefferson City, MO 65102 or by phone at (573) 751-7840 or email atwendy.vit@dnr.mo.gov.

Sincerely,

# 2:TI~~::RAM Kyra L. Moore
Director

KLM:spc

Enclosures:

Copy of rule published in CSR Copy of commission signature page certifying Missouri Air Conservation Commission adoption Copy of technical support documentation for rule (if applicable) Copies of public hearing notices Copy of public hearing transcript introductory statement Copy of MO Reg proposed rulemaking Copy of MO Reg order of rulemaking with comments/responses Mark-Up of Existing Federally-Approved State Regulation(s)

c: Missouri Air Conservation Commission

Celebrating 

### 40 years 

### of taking care 

### of Missouri's natural resources. To learn more about the Missouri Department 

### of Natural Resources visit dnr.mo.gov.

## Chapter 5—Air Quality Standards and Air Pollution Control Rules Specific to the St. Louis Metropolitan Area 10 CSR 10-5

(1) General.

(A) For purposes of this regulation theword reduction is defined as any heated process, including rendering, cooking, drying,dehydrating, digesting, evaporating and protein concentrating. Animal matter is de fined as any product or derivative of animal life.

(B) The provisions of this regulation shall not apply to any device, machine, equipment or other contrivance used exclusively for the processing of food for human consumption in
food service establishments.

(C) For purposes of this regulation, a food
service establishment shall be defined as follows: any fixed or mobile restaurant; coffeeshop; cafeteria; short order cafe; luncheonette; grill; tearoom; sandwich shop; soda fountain; tavern; bar; cocktail lounge; night club; roadside stand; industrial feeding establishment; private, public or nonprofit organization or institution routinely servingfood; catering kitchen, commissary or similar place in which food or drink is placed forsale or for service on the premises or elsewhere; and any other eating or drinking establishment or operation where food is served or provided for the public with or without charge.

(2) Odor Control Equipment Required on
Reduction Processes.

(A) No person shall operate or use anydevice, machine, equipment or other contrivance for the reduction of animal matter unless all gases, vapors and gas-entrained effluents from the facility are incinerated at a temperature of not less than twelve hundred degrees Fahrenheit (1200 °F) for a period of not less than 0.3 second, or processed in a manner as determined by the director to be equally or more effective for the purpose of air pollution control.

(B) A person incinerating or processinggases, vapors or gas-entrained effluents pursuant to this rule shall provide, properly install and maintain, in good working order and in operation, devices as specified by the director for indicating temperature, pressure or other operating conditions.

(3) Other Odor Control Measures Required.

(A) Effective devices and/or measures shall be installed and operated so that no vent, exhaust pipe, blow-off pipe or opening of any kind shall discharge into the outdoor air any odorous matter, vapors, gases or dusts or any combination which create odors or other nuisances in the neighborhood of the plant.

(B) Odor-producing materials shall be
stored and handled in a manner so that odors produced from the materials are confined. Accumulation of odor-producing materialsresulting from spillage or other escape is prohibited.

(C) Odor-bearing gases, vapors, fumes or dusts arising from materials in process shallbe confined at the point of origin so as to prevent liberation of odorous matter. Confined gases, vapors, fumes or dusts shall be treated before discharge to the atmosphere, as required in subsection (3)(A).

(4) Enclosure of Building May Be Required. Whenever dust, fumes, gases, mist, odorous matter, vapors or any combination thereof escape from a building used for processing of
animal matter in a manner and amount as to cause a violation of 10 CSR 10-5.160, the director may order that the building(s) in which processing, handling and sto rage are done be tightly closed and ventilated in a way that all air and gases and air or gas-borne material leaving the building are treated by
incineration or other effective means for
removal or destruction of odorous matter or other air contaminants before discharge into the open air.

AUTHORITY: section 643.050, RSMo 2000.* Original rule filed March 14, 1967, effective March 24, 1967. Amended: Filed July 19, 2002, effective April 30, 2003.

*Original authority: 643.050, RSMo 1965, amended 1972, 1992, 1993, 1995.

10 CSR 10-5.180 Emission of Visible Air
Contaminants From Internal Combustion Engine (Rescinded November 30, 2002)

AUTHORITY: section 643.050, RSMo 1994. Original rule filed March 14, 1967, effective March 24, 1967. Rescinded Filed Feb. 28, 2002, effective Nov. 30, 2002.

Op. Atty. Gen. No. 331, Shell (11-15-71). The state of Missouri has the authority to inspect for “air pollution control devices” which may be installed on motor vehicles as a requirement to comply with applicableemission regulations, but whether the regulations and inspections would accomplish thepurpose of “enforcing compliance with applicable emission standards” which are federalstandards, and whether the preemption provision of 42 U.S.C.A., Section 1857f-6a, has been complied with are questions that only the appropriate federal officials can answer.

10 CSR 10-5.190 Approval of Planned
Installations (Rescinded April 11, 1980) AUTHORITY: section 203.050, RSMo 1978. Original rule filed March 14, 1967, effective March 24, 1967. Amended: Filed Jan. 31, 1972, effective Feb. 10, 1972. Amended: Filed Aug. 25, 1972, effective Sept. 4, 1972. Amended: Filed Aug. 16, 1977, effective Feb. 11, 1978. Rescinded: Filed Dec. 10, 1979, effective April 11, 1980.

Op. Atty. Gen. No. 331, Shell (11-15-71)

. The Missouri Air Conservation Commission has the authority under Chapter 203, RSMo(1969) to provide for the equivalent of a construction permit system by promulgating regulations to require the submission of plans and specifications for approval before any person may construct any facility which will cause air pollution, but that the commissionhas no such authority regarding an equivalent permit system for the operation of existing facilities which are the source of air pollution.

10 CSR 10-5.200 Measurement of Emissions of Air Contaminants (Rescinded April 9, 1992)

AUTHORITY: section 203.050, RSMo 1986. Original rule filed March 14, 1967, effective March 24, 1967. Rescinded: Filed Oct. 16, 1991, effective April 9, 1992.

10 CSR 10-5.210 Submission of Emission
Information (Rescinded November 12, 1984)

AUTHORITY: section 203.050, RSMo 1978. Original rule filed March 14, 1967, effective March 24, 1967. Amended: Filed Aug. 25, 1972, effective Sept. 4, 1972. Rescinded: Filed June 13, 1984, effective Nov. 12, 1984.

Op. Atty. Gen. No. 331, Shell (11-15-71).
The Missouri Air Conservation Commission does not have any specific authority torequire the installation of emission monitoring devices, but does have the authority to require reports from sources of air pollutionrelating to rate, period of emission and composition of effluent, and to make such information available to the public, unless any such information is “confidential” as defined by section 203.050.4, RSMo (1969).

10 CSR 10-5.220 Control of Petroleum Liquid Sto rage, Loading and Transfer

PURPOSE: This rule restricts volatile organic compound emissions from the handling of

CODE OF STATE REGULATIONS 7 J ASON K ANDER (10/31/14) Secretary of Statepetroleum liquids in five specific areas: petroleum sto rage tanks with a capacitygreater than forty thousand gallons, the loading of gasoline into delivery vessels, the transfer of gasoline from delivery vessels into
storage containers, gasoline delivery vessels and the fueling of motor vehicles from sto rage containers. This rule is required to achievethe federally mandated reduction of hydrocarbon emissions in the St. Louis metropolitan area that contribute to the formation of

ozone.

PUBLISHER’S NOTE:  The secretary of state has determined that the publication of theentire text of the material which is incorporated by reference as a portion of this rule would be unduly cumbersome or expensive. This material as incorporated by reference in this rule shall be maintained by the agency at its headquarters and shall be made available to the public for inspection and copying at no more than the actual cost of reproduction.This note applies only to the reference material. The entire text of the rule is printed
here.

(1) Applicability.

(A) This rule shall apply throughout St. Louis City and Jefferson, St. Charles, Franklin
and St. Louis Counties.

(B) Compliance with this rule does notrelieve the owner or operator of the responsibility to comply with other applicable governmental requirements.

(C) Exemptions to This Rule and/or Specific Areas of This Rule.
1. Petroleum sto rage tanks. Subsection (3)(A) of this rule shall not apply to petroleum sto rage tanks that— A. Store processed and/or treatedpetroleum or condensate at a drilling and production installation prior to custody transfer; B. Contain a petroleum liquid with a true vapor pressure less than 27.6 kilopascals (kPa) (4.0 psia) at ninety degrees Fahrenheit (90 °F); C. Are welded construction, and equipped with a metallic-type shoe primary seal and have a shoe-mounted secondary sealor closure devices of demonstrated equivalence approved by the staff director; and D. Store waxy, heavy pour crude oil. 2. Gasoline loading.

A. Subsection (3)(B) of this rule shall not apply to a gasoline loading installation
whose ave rage monthly throughput of gasoline is less than or equal to one hundred twenty thousand (120,000) gallons when averaged over the most recent calendar year, provided the gasoline loading installation loads gasoline by submerged filling and— (I) Owners or operators of gasoline loading installations submit a report to the staff director on a form supplied by the department stating the gasoline throughput for each month of the previous calendar year. The report shall be submitted no later than February 1 of each year; (II) Delivery vessels purchased after December 31, 1995, are Stage I equipped; (III) Owners or operators of gasoline loading installations maintain records of gasoline throughput and gasoline delivery;
and (IV) Delivery vessels operated by an exempt installation do not deliver to Stage I controlled tanks unless the delivery vessel is equipped with and employs Stage I controls. B. A gasoline loading installation thatfails to meet the requirements of the exemption in subparagraph (1)(C)2.A. of this rule for one (1) calendar year shall not qualify for the exemption again. 3. This rule does not apply to stationary gasoline tanks with a capacity of less than or equal to five hundred (500) gallons. 4. Subsection (3)(E) of this rule does not apply to any gasoline dispensing facility (GDF) with one thousand (1,000) gallon or smaller tank(s) and monthly throughput of less than or equal to ten thousand (10,000) gallons of gasoline through the tanks. 5. Paragraph (3)(C)2. of this rule doesnot apply to gasoline transfers made to storage tanks equipped with floating roofs or their equivalent. 6. Subsection (3)(C) of this rule does not apply to any sto rage tank having a capacity less than or equal to two thousand (2,000) gallons used exclusively for the fueling of agricultural equipment. 7. Subsection (3)(E) of this rule does not apply to any stationary sto rage tank used primarily for the fueling of agricultural equipment.

(2) Definitions.

(A) Agricultural equipment—Any equipment used exclusively for agricultural purposes on land owned or leased for the production of farm products.

(B) Definitions of certain terms specified in this rule, other than those defined in this rule section, may be found in 10 CSR 10-
6.020.

(3) General Provisions.

(A) Petroleum Sto rage Tanks.

1. No owner or operator of petroleum
storage tanks shall cause or permit the storage in any stationary sto rage tank of more than forty thousand (40,000) gallons capacity of any petroleum liquid having a true vapor pressure of one and five-tenths (1.5) pounds per square inch absolute (psia) or greater at ninety degrees Fahrenheit (90 °F), unless the
storage tank is a pressure tank capable of maintaining working pressures sufficient atall times to prevent volatile organic compound (VOC) vapor or gas loss to the atmosphere or is equipped with one (1) of the following vapor loss control devices: A. A floating roof, consisting of a pontoon type, double-deck type or internal floating cover or external floating cover, that rests on the surface of the liquid contents and is equipped with a closure seal(s) to close the space between the roof edge and tank wall. Storage tanks with external floating roofsshall meet the additional following requirements: (I) The sto rage tank must be fitted
with— (a) A continuous secondary seal extending from the floating roof to the tank wall (rim-mounted secondary seal); or (b) A closure or other device approved by the staff director that controls VOC emissions with an effectiveness equal to or greater than a seal required under subpart (3)(A)1.A.(I)(a) of this rule; (II) All seal closure devices must meet the following requirements: (a) There are no visible holes, tears or other openings in the seal(s) or seal fabric; (b) The seal(s) is intact and uniformly in place around the circumference of the floating roof between the floating roof and the tank wall; and (c) For vapor-mounted primary seals, the accumulated area of gaps exceeding 0.32 centimeters, one-eighth inch (1/8") width, between the secondary seal and the

tank wall shall not exceed 21.2 cm 2 per meter of tank diameter (1.0 in 2 per foot of tank diameter); (III) All openings in the external floating roof, except for automatic bleeder vents, rim space vents and leg sleeves, must be equipped with— (a) Covers, seals or lids in the closed position except when the openings are in actual use; and (b) Projections into the tank which remain below the liquid surface at all times; (IV) Automatic bleeder vents must be closed at all times except when the roof is floated off or landed on the roof leg supports; (V) Rim vents must be set to openwhen the roof is being floated off the leg supports or at the manufacturer’s recommended setting; and

8 CODE OF STATE REGULATIONS (10/31/14) J ASON K ANDER Secretary of State 

## 10 CSR 10-5—DEPARTMENT OF NATURAL RESOURCES Division 10—Air Conservation Commission

## Chapter 5—Air Quality Standards and Air Pollution Control Rules Specific to the St. Louis Metropolitan Area 10 CSR 10-5

(VI) Emergency roof drains must be provided with slotted membrane fabric covers or equivalent covers which cover at least ninety percent (90%) of the area of the opening; B. A vapor recovery system with all
storage tank gauging and sampling devices gas-tight, except when gauging or sampling is taking place. The vapor disposal portion of the vapor recovery system shall consist of anabsorber system, condensation system, membrane system or equivalent vapor disposal system that processes the vapor and gases from the equipment being controlled; or C. Other equipment or means of equal efficiency for purposes of air pollution control that may be approved by the staff
director.2. Control equipment described in subparagraph (3)(A)1.A. of this rule shall not be allowed if the petroleum liquid other than gasoline has a true vapor pressure of 11.1 psia or greater at ninety degrees Fahrenheit (90 °F). All sto rage tank gauging and sampling devices shall be gas-tight except when gauging or sampling is taking place. 3. Reporting and record keeping shall be per subsection (4)(A) of this rule.

(B) Gasoline Loading.

1. No owner or operator of a gasoline loading installation or delivery vessel shall cause or permit the loading of gasoline into any delivery vessel from a gasoline loadinginstallation unless the gasoline loading installation is equipped with a vapor recovery system or equivalent. This system or system equivalent shall be approved by the staff director and the delivery vessel shall be in compliance with subsection (3)(D) of this
rule. 2. Gasoline loading shall be accomplished in a manner that the displaced vaporsand air will be vented only to the vapor recovery system. Measures shall be taken to prevent liquid drainage from the loading device when it is not in use or to accomplish completedrainage before the loading device is disconnected. The vapor disposal portion of the vapor recovery system shall consist of one (1) of the following: A. An absorber system, condensation system, membrane system, or equivalent vapor disposal system that processes the vapors and gases from the equipment being controlled andlimits the discharge of VOC into the atmosphere to ten (10) milligrams of VOC vapor per liter of gasoline loaded; B. A vapor handling system that directs the vapor to a fuel gas system; or C. Other equipment of an efficiency equal to or greater than subparagraph (3)(B)2.A. or B. of this rule if approved by the staff director. 3. Reporting and record keeping shall be per subsection (4)(B) of this rule.

(C) Gasoline Transfer at GDFs.

1. No owner or operator of a gasoline
storage tank or delivery vessel shall cause orpermit the transfer of gasoline from a delivery vessel into a gasoline sto rage tank with acapacity greater than five hundred (500) gallons and less than or equal to one thousand (1,000) gallons unless— A. The gasoline sto rage t ank isequipped with a submerged fill pipe extending unrestricted to within six inches (6") of the bottom of the tank and not touching the bottom of the tank, or the sto rage tank is equipped with a system that allows a bottom fill condition; B. All gasoline sto rage tank caps and fittings are vapor-tight when gasoline transfer is not taking place; and C. Each gasoline sto rage tank is vented via a conduit that is— (I) At least two inches (2") inside diameter; and (II) At least twelve feet (12') in height above grade; and(III) Equipped with a pressure/vacuum valve that is certified by the California Air Resources Board (CARB) at three inches water column pressure/eight inches water column vacuum (3"wcp/8"wcv) except whenthe owner or operator provides documentation that the vapor recovery system is CARBcertified for a different valve and will not function properly with a 3"wcp/8"wcv valve. 2. No owner or operator of a gasoline
storage tank or delivery vessel shall cause orpermit the transfer of gasoline from a delivery vessel into a gasoline sto rage tank with a capacity greater than one thousand (1,000) and less than forty thousand (40,000) gallons
unless— A. The gasoline sto rage t ank isequipped with a Stage I vapor recovery system that is certified by a CARB Executive Order as having a collection efficiency of at least ninety-eight percent (98%); B. The delivery vessel to these tanks is in compliance with subsection (3)(D) of this rule;C. All vapor ports are poppeted fittings; D. The delivery vessel is reloaded at installations complying with the provisions of subsection (3)(B) of this rule; E. The vapor recovery system employs one (1) vapor line per product line during the transfer. The staff director may approve other delivery systems submitted to the department with test data demonstrating compliance with subparagraph (3)(C)2.A. of this rule; F. All vapor hoses are at least three inches (3") inside diameter; and G. All product hoses are less than or equal to four inches (4") inside diameter. 3. The director may approve a vapor recovery system or component that deviates from the requirements of subparagraph(3)(C)2.A. of this rule when provided documentation that— A. The system or component has a collection efficiency of at least ninety-eight percent (98%); and B. Compliance with the requirements of subparagraph (3)(C)2.A.of this rule would lead to noncompliance with other state orfederal regulations or to improper functioning of the gasoline sto rage tank system. 4. Aboveground gasoline sto rage tanks at GDFs shall not have a capacity greater than one thousand (1,000) gallons. 5. This subsection does not prohibit safety valves or other devices required by government regulations.

(D) Gasoline Delivery Vessels.

1. No owner or operator of a gasoline delivery vessel shall operate or use a gasoline delivery vessel which is loaded or unloaded at an installation subject to subsection (3)(B) or (3)(C) of this rule unless—A. The delivery vessel is tested annually to demonstrate compliance with the test method specified in 40 CFR 63.425(e); B. The owner or operator obtains thecompleted test results signed by a representative of the testing installation upon successful completion of the leak test. C. A copy of the vessel’s current test results are kept with the delivery vessel at all times and made immediately available to the staff director upon request; and D. The delivery vessel is repaired bythe owner or operator and retested within fifteen (15) business days of testing if it does not meet the leak test criteria of subparagraph (3)(D)1.A. of this rule. 2. An owner or operator of a gasoline delivery vessel who can demonstrate to the
satisfaction of the staff director that the vessel has passed a current annual leak test in
another state shall be deemed to have satisfied the requirements of subparagraph (3)(D)1.A. of this rule, if the other state’s leak test program requires the same gauge pressure and test procedures as specified in subparagraph (3)(D)1.A. of this rule. 3. Reporting and record keeping shall be performed as specified in subsection (4)(C)
of this rule.

CODE OF STATE REGULATIONS 9 J ASON K ANDER (10/31/14) Secretary of State4. This subsection does not prohibit safety valves or other devices required by government regulations.

(E) Fueling of Motor Vehicles at GDFs.

1. GDFs not equipped with a Stage II vapor recovery system. Owners or operators
shall— A. Employ vapor-tight tank gaugingand sampling sites or ports, valves, breakaways, joints, and disconnects on the vapor recovery systems to prevent emissions of volatile organic compounds except during gauging or sampling; and B. Ensure that motor vehicle refueling meets the requirements of 40 CFR 80.22(j)promulgated June 26, 1996, and hereby incorporated by reference in this rule, as published by the Office of Federal Register, U.S. National Archives and Records, 700 Pennsylvania Avenue NW, Washington, D.C.
20408. This rule does not incorporate any subsequent amendments or additions. 2. GDFs equipped with a Stage II vapor
recovery system. A. Owners or operators shall—

(I) Comply with the requirements of subparagraphs (3)(E)1.A.–B. of this rule. (II) Maintain the Stage II vapor recovery system in good working order inaccordance with the manufacturer’s specifications and with no indication of visible liquid leaks. Vapor recovery system components may only be replaced with components that have equivalent performance; (III) Post operation instructions conspicuously in the gasoline dispensing area for the vapor recovery system in use at each GDF. The instructions shall clearly describe how to fuel vehicles correctly with vapor recovery nozzles utilized at that GDF. The instructions shall also include a warning that repeated attempts to continue dispensing gasoline after the system has indicated that the vehicle fuel tank is full may result in spillage of gasoline; (IV) Decommission the Stage II vapor recovery system no later than December31, 2015. The decommissioning must be performed in accordance with the department’s Stage II Decommissioning Checklist. B. The staff director shall identify and list specific defects that substantially impair the effectiveness of components or systemsused for the control of gasoline vapors resulting from motor vehicle fueling operations. This ongoing list shall be used by the staffdirector as a basis for marking the components or systems out-of-order and shall be made available to any GDF with a Stage II vapor recovery system in place.C. Upon the staff director’s identification of substantial defects in equipment or installation of a Stage II vapor recovery system, the system or components shall be marked “out-of-order” and no person shalluse or permit the use of that system or component until those defects and all other defects have been repaired, replaced, or adjusted toestablish compliance. The components or system may be released into operation when the staff director has reinspected the installation; found the system and components to be ingood working order; and removed the “out-oforder” notice. The staff director shall reinspect the previously marked “out-of-order” system or component and other noted defects as expeditiously as possible after notification from the operator that the repairs have been completed. In no case shall the reinspection be more than four (4) business days from the operator’s notification that the repairs have been completed. In those cases in which the reinspection cannot be scheduled within the required time, the owner or operator mayremove the “out-of-order” notice with permission of the staff director. If reinspectionreveals that compliance has not been established, the system or components shall remain tagged “out-of-order.” The staff director shall conduct a second reinspection within seven (7) business days from the operator’s notification that repairs have been completed. 3. After the effective date of this rule, no owner or operator of a GDF may install a new Stage II vapor recovery system.

(F) Permits Required.

1. No owner or operator of a GDF subject to subsections (3)(C) or (3)(E) of this rule may construct or modify a Stage I or Stage II vapor recovery system without obtaining a construction permit according to subsection (3)(G) of this rule; and2. No owner or operator of a GDF subject to subsections (3)(C) or (3)(E) of this rule shall operate without an operating permit obtained according to subsection (3)(H) of
this rule.

(G) Construction Permits for Vapor Recovery Systems for New GDFs, Vapor Recovery System Modification for Existing GDFs, and Stage I experimental technology.
1. Construction of a new GDF that requires a Stage I vapor recovery system, decommission of an existing Stage II vapor recovery system, or major modification to anexisting GDF. An owner or operator constructing a new GDF that requires a Stage I vapor recovery system, decommissioning an existing Stage II vapor recovery system, or modifying an existing vapor recovery system such that the fixed capital costs of the new components will exceed fifty percent (50%)of the fixed capital cost of a new gasoline dispensing system (including only those components directly related to gasoline dispensing
and sto rage) shall— A. Submit an application on a form supplied by the department for a permit to construct at least thirty (30) days prior to beginning construction. The application shall
include: (I) Complete diagrams and a thorough description of the planned installation; (II) Plumbing diagrams including vent lines and material of all underground and aboveground plumbing; (III) For gasoline sto rage tanks subject to paragraph (3)(C)2. of this rule, current CARB Executive Orders for the proposed Stage I vapor recovery system; (IV) Detailed description of the
storage tank(s); and (V) Schedule of construction; B. Obtain a construction permit prior to beginning construction; C. Display the construction permit in a prominent location during construction; D. Establish compliance with all rules and requirements of Division 10 of Title 10 of
the Code of State Regulations ; E. Obtain staff director approval of final test methods and procedures that will be used to demonstrate compliance; F. Meet the testing requirements in subparagraph (3)(H)1.B. of this rule; and G. Obtain and maintain on-site, in aprominent location, the current operating permit from the director for the site and the specific vapor recovery system that was installed. The operating permit shall be maintained according to subsection (3)(H) of this rule. 2. Minor modification to existing GDF. An owner or operator of an existing GDF modifying an existing vapor recovery system such that the fixed capital costs of the new components will not exceed fifty percent(50%) of the fixed capital cost of a new gasoline dispensing system (including only thosecomponents directly related to gasoline dispensing and sto rage) shall—A. Submit a construction permit notification prior to construction for projects thatinclude, but are not limited to, any modification that— (I) Requires breaking concrete in an area within fifteen (15) feet of the vapor lines or vent lines; (II) Modifies vapor lines or vent lines themselves; (III) Affects the operation of the
vapor recovery system; or(IV) Could result in improper functioning of the vapor recovery system; B. Supply any information requestedby the staff director for the specific installation. Such information may include, but is

10 CODE OF STATE REGULATIONS (10/31/14) J ASON K ANDER Secretary of State 

## 10 CSR 10-5—DEPARTMENT OF NATURAL RESOURCES Division 10—Air Conservation Commission

## Chapter 5—Air Quality Standards and Air Pollution Control Rules Specific to the St. Louis Metropolitan Area 10 CSR 10-5

not limited to, plumbing diagrams, includingvapor or vent lines; material of all underground and aboveground plumbing; current CARB executive orders for the proposed vapor recovery system and equipment; and proof of compliance with all rules and requirements of Division 10 of Title 10 of the Code of State Regulations ; C. Modify the vapor recovery system in accordance with the rules and requirements
of Division 10 of Title 10 of the Code of State Regulations . If, after review of the application, or inspection of the modification to the vapor recovery system, it is discovered that the modification is not in compliance with the rules and requirements of Division 10 of Title
10 of the Code of State Regulations , the owner or operator will be subject to enforcement action, and must bring the facility back into compliance with the rules and requirements of
Division 10 of Title 10 of the Code of State Regulations ; D. Meet the testing requirements in paragraph (3)(H)1. of this rule; and E. Upon completion of testing, obtain and display, in a prominent location, on-site the current operating permit from the director for the specific site and the specific vaporrecovery system that was installed. The operating permit shall be maintained according to subsection (3)(H) of this rule. 3. Experimental Stage I technology. The director may approve Stage I experimental technology for a specific GDF. Experimental technology may be approved for up to three (3) years for a limited number of GDFs under specific conditions determined by the staffdirector. GDFs applying for approval of experimental technology shall— A. Submit an application for director approval at least ninety (90) days prior to beginning construction. The application shall include, but not be limited to:(I) Complete diagrams and a thorough description of the planned installation; (II) Plumbing diagrams including vent lines and material of all underground and aboveground plumbing; and (III) Standards, test data, history,and related information for the proposed system; B. Submit to the staff director adetailed plan for the construction and operation of the system. The plan shall include a description of the planned testing and record keeping for the GDF. The director may issue the construction permit when all conditions of
the testing GDF are deemed satisfactory; C. Display the construction permit in a prominent location during construction; D. Install monitoring equipment toprove that the vapor recovery system is leaktight if requested by the staff director; and E. Upon completion of testing, obtain and maintain on-site, in a prominent location, a current operating permit from the director for the specific innovative technology that is in operation. The permit shall specify the technology, the location, and the time period the technology will be tested. 4. Emergency Repairs.

A. Owners or operators of GDFs requiring emergency repair or replacement of
vapor recovery system components may immediately begin corrective construction if the construction is in response to an accident
or event that— (I) Creates an abnormally high threat of fire; (II) Poses an environmental hazard by allowing release of liquid product onto the ground or abnormal release of vapor into the air; and/or (III) Threatens public safety; andB. Owners or operators of GDFs electing to make emergency repair or replacement per subparagraph (3)(G)4.A. of this rule shall contact the department within forty-eight (48) hours of the commencement of the repair or replacement to determine what future action is required for compliance with this rule. 5. Owners or operators of GDFs making minor modifications per paragraph (3)(G)2.of this rule may begin modification upon submittal of the construction permit notification.
6. The director shall issue a construction permit or a permit rejection within thirty (30)days of receipt of all construction permit applications submitted per paragraph (3)(G)1. of
this rule. 7. Owners or operators of GDFs shallpay the department a fee of one hundred dollars ($100) for each construction permit application submitted in accordance with subsection (3)(G) of this rule.

(H) Operating Permits. All owners or operators of installations subject to subsection (3)(C) or (3)(E) of this rule shall apply to the director for an operating permit. 1. Completion of construction. To obtain an operating permit after the completion of construction, the owner or operator of a GDF
shall— A. Apply to the director for an operating permit within thirty (30) days of construction completion;B. Conduct and pass a departmentapproved pressure decay test, pressure/vacuum valve test, and, where a Stage II vapor recovery system is in place, a dynamic back pressure/liquid bloc kage test; C. Schedule the test and notify the staff director at least seven (7) days prior to the test date. The staff director may observe the test, but it is not required that the staff director be present and observe the test;
D. Provide the test results to the staff director;
E. Demonstrate that the installation maintains a system of record keeping that meets the requirements of subsection (4)(D) of this rule; and F. Establish compliance with all rules and requirements of Division 10 of Title 10 of
the Code of State Regulations

. 2. Renewal of operating permits. The operating permit is renewable on the date specified in the initial operating permit and for periods of three (3) years after the initial permit term expires. In order to renew the operating permit the owner or operator of a
GDF shall— A. Apply to the director for renewal of the operating permit and test within ninety (90) days prior to the renewal date;
B. Demonstrate that the GDF maintained all vapor recovery system components in good operating order during the preceding operating permit term including prompt efforts to establish compliance following “out-of-order” notices;C. Conduct and pass a departmentapproved pressure decay test, pressure/vacuum valve test, and, where a Stage II vapor recovery system is in place, a dynamic back pressure/liquid bloc kage test, prior to the expiration date of the permit; D. Schedule the test and notify the staff director at least seven (7) days prior to the test date. The staff director may observe the test, but it is not required that the staff director be present and observe the test;
E. Provide the test results to the staff director; andF. Maintain records according to subsection (4)(D) of this rule. 3. Owners or operators of an installationusing a vapor recovery system that is decertified by CARB shall establish compliance with this rule within one (1) year or by the nextrenewal date of the operating permit whichever is longer. Failure to establish compliancewill result in nonrenewal of the operating permit. 4. Owners or operators of GDFs shallpay the department a fee of one hundred dollars ($100) for each operating permit.

(I) Owner/Operator Compliance. The owner or operator of a vapor recovery system subject
to this rule shall— 1. Operate the vapor recovery system and the gasoline loading equipment in a manner that prevents—

CODE OF STATE REGULATIONS 11 J ASON K ANDER (10/31/14) Secretary of StateA. Gauge pressure from exceeding four thousand five hundred (4,500) pascals (eighteen inches (18") of H 2 O) in the delivery
vessel; B. A reading equal to or greater than one hundred percent (100%) of the lower explosive limit (LEL), measured as propane at two point five (2.5) centimeters from all points on the perimeter of a potential leaksource when measured by the method referenced in 10 CSR 10-6.030(14)(E) during loading or transfer operations; and C. Visible liquid leaks during loading or transfer operations; and 2. Repair and retest within fifteen (15) days, a vapor recovery system that exceeds the limits in paragraph (3)(I)1. of this rule;
and 3. Reporting and record keeping shall be per subsection (4)(D) of this rule.

(4) Reporting and Record Keeping.

(A) Owners and operators of petroleum
storage tanks subject to subsection (3)(A) of
this rule shall maintain written records of maintenance (both routine and unscheduled) performed on the tanks, all repairs made, the results of all tests performed, and the type and quantity of petroleum liquid stored in them. Records shall be kept for two (2) years
and made available to the staff director within five (5) business days of a request.

(B) Owners or operators of gasoline loading installations subject to subsection (3)(B)of this rule shall keep complete records documenting the number of delivery vessels
loaded and their owners. Records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request.

(C) Owners or operators of gasoline delivery vessels subject to subsection (3)(D) of thisrule shall keep records of all tests and maintenance performed on the vessels. Records shall be kept for two (2) years and made available to the staff director within five (5) business daysof a request. Also a copy of the vessel’s current Tank Truck Tightness Test results shall be kept with the delivery vessel at all times and made immediately available to the staff director upon request.

(D) Owner/Operator Compliance. The owner or operator of a vapor recovery system subject to subsection (3)(C), (3)(E), or (3)(I)of this rule shall maintain records of department permits, inspection reports, enforcement documents, training certifications, gasoline deliveries, routine and unscheduled maintenance, repairs, and all results of tests conducted. Unless otherwise specified in this rule, records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request.

(5) Test Methods.

(A) Gasoline Loading. Gasoline loading testing procedures to determine compliance with subparagraph (3)(B)2.A. of this ruleshall be according to 10 CSR 10-6.030 subsection (14)(A) or by any method determined by the staff director. The staff director, at any time, may monitor an installation subject tosubsection (3)(B) of this rule to confirm compliance with this rule.

(B) Gasoline Delivery Vessels. Testing procedures for gasoline delivery vessels to determine compliance with subsection (3)(D) of this rule shall be according to 10 CSR 10- 6.030 subsection (14)(B) or by any method determined by the staff director. The staff director, at any time, may monitor a gasoline delivery vessel subject to subsection (3)(D) of this rule to confirm compliance with this
rule.

(C) Fueling of Motor Vehicles and Gasoline Transfer at GDFs. The staff director, at anytime, may monitor a GDF subject to subsection (3)(C) or (3)(E) of this rule to confirm compliance with this rule. The staff directormay require a leak test, a back pressure blockage test, a pressure/vacuum valve test, or may require any test or monitoring procedure in order to determine compliance with this rule.

(D) All emission controls that are approvedby the director will not be considered federally enforceable and will not shield a sourcefrom the obligation to comply with the underlying federal emission controls until submitted to EPA and approved by EPA in the state implementation plan.

AUTHORITY: section 643.050, RSMo Supp. 2013.* Original rule filed March 14, 1967, effective March 24, 1967. Amended: Filed Jan. 31, 1972, effective Feb. 10, 1972. Amended: Filed Aug. 25, 1972, effective Sept. 4, 1972. Amended: Filed May 12, 1976, effective Oct. 11, 1976. Amended: Filed Aug. 16, 1977, effective Feb. 11, 1978. Amended: Filed March 13, 1980, effective Sept. 12, 1980. Amended: Filed Dec. 5, 1980, effective May 11, 1981. Amended: Filed Nov. 2, 1984, effective May 11, 1985. Amended: Filed Dec. 3, 1985, effective Oct.1, 1986. Amended: Filed Oct. 4, 1988, effective March 11, 1989. Amended: Filed Nov. 27, 1989, effective May 24, 1990. Rescindedand Readopted: Filed Aug. 15, 1994, effective April 30, 1995. Amended: Filed May 15, 1995, effective Dec. 30, 1995. Amended: Filed Jan. 16, 1996, effective Sept. 30, 1996. Amended: Filed Dec. 28, 1998, effective Aug. 30, 1999. Amended: Filed Jan. 2, 2007, effective Sept. 30, 2007. Amended: Filed Feb. 27, 2014, effective Nov. 30, 2014.

*Original authority: 643.020, RSMo 1965, amended 1972, 1992, 1993, 1995, 2011.

10 CSR 10-5.230 Circumvention (Rescinded September 28, 1990)

AUTHORITY: section 203.050, RSMo 1986. Original rule filed March 14, 1967, effective March 24, 1967. Rescinded: Filed April 18, 1990, effective Sept. 28, 1990.

10 CSR 10-5.240 Additional Air Quality Control Measures May be Required When
Sources Are Clustered in a Small Land
Area (Rescinded July 30, 2014)

AUTHORITY: section 643.050, RSMo 1994. Original rule filed March 14, 1967, effective March 24, 1967. Rescinded: Filed Oct. 9, 2013, effective July 30, 2014.

Op. Atty. Gen. No. 331, Shell (11-15-71)

. The Missouri Air Conservation Commission has the authority under Chapter 203, RSMo (1969) and the Constitution of Missouri to enforce without delay the provisions of Chapter 203, RSMo (1969) and standards,regulations corresponding, through administrative procedures, and injunctive relief.

10 CSR 10-5.250 Time Schedule for Compliance (Rescinded December 30, 2008)

AUTHORITY: section 643.050, RSMo 1994. Original rule filed March 14, 1967, effective March 24, 1967. Amended: Filed Jan. 31, 1972, effective Feb. 10, 1972. Rescinded: Filed April 17, 2008, effective Dec. 30, 2008.

10 CSR 10-5.260 Rules for Controlling Emissions During Periods of High Air
Pollution Potential (Rescinded October 11, 1984)

AUTHORITY: section 203.050, RSMo 1978. Original rule filed Sept. 8, 1970, effective Sept. 18, 1970. Amended: Filed Jan. 31, 1972, effective Feb. 10, 1972. Rescinded: Filed May 11, 1984, effective Oct. 11, 1984.

Op. Atty. Gen. No. 331, Shell (11-15-71)

. The Missouri Air Conservation Commission has the authority under Chapter 203, RSMo

12 CODE OF STATE REGULATIONS (10/31/14) J ASON K ANDER Secretary of State 

## 10 CSR 10-5—DEPARTMENT OF NATURAL RESOURCES Division 10—Air Conservation Commission

# --------------------------------- Order of Rulemaking

The Missouri Air Conservation Commission 

## ADOPTS the following action

on this 21st day of July, 2014:

10 CSR 10-5.220 (amendment) 

## Control of Petroleum Liquid Storage, Loading and Transfer

# _7~L~£::::'Vy.!::::l/~L-CJ----!)L-I-A~**=====-~---,** Chairman

, Vice Chairman



## , Member

_________________________________ , Member

_________________________________ , Member

_________________________________ , Member

_________________________________ , Member

## 1 Technical Support Document for the Amendment to
10 CSR 10-5.220 Control of Petroleum Liquid Storage, Loading and Transfer Removal of Stage II Vapor Recovery Requirements (Prepared January 9, 2013 for 10 CSR 10-5.2 20, rulemaking effective date is November 30, 2014)

I. Background and Purpose. Missouri rule 10 CSR 10-5.220, Control of Petroleum Liquid Storage, Loading and Transfer regulates the emissions of volatile organic compounds (VOCs) from the petroleum product storage and distribution netw ork. This rule includes requirements for
control of VOC emissions from motor vehicle refueling in the St. Louis area using Stage II vapor recovery systems. Stage II system s capture displaced vapors from vehicle fuel tanks during refueling and return the vapor s to the underground st orage tanks at the gasoline dispensing facility. Th e Stage II requirements of this rule were promulgated in the late 1980’s and were incorporated into Missouri’s State Implementation Plan (SIP) as part of the control strategies for the one-hour ozone National Ambient Air Quality Standard (NAAQS).

Onboard refueling vapor recover (ORVR) is a second method of controlling the vapor displaced during motor vehicle refueling. The displaced vapors are captured before they exit the vehicle fill pipe and are stored in activated carbon can isters onboard the vehicle. When the vehicle’s engine is started, the vapors are purged from the activated carbon into the engine where they are burned as fuel.

Automobile manufacturers bega n installing ORVR systems on new passenger vehicles in 1998. Currently, more than 75% of gasolin e refueling nationwide occurs with ORVRequipped vehicles, so Stage II programs have become largely redundant control systems and Stage II vapor recovery systems achieve an ever-declining emissions benefit as ORVR-equipped vehicles continue to enter the motor vehicle fleet.

In its final rule published in the May 16, 2012, Federal Register (77 FR 28772), the U.S. Environmental Protection Agency (EPA) has determined that ORVR technology is in widespread use throughout the motor vehicl e fleet for purposes of controlling motor vehicle refueling emissions. This federal rule allows states to re move Stage II programs
from their SIP if certa in criteria are met.

Because the Stage II controls in 10 CSR 10-5.220 are part of Missouri’ s approved SIP, if the state decides to terminate the Stage II program, it must submit a SIP revision to EPA that includes the appropriate re visions to the Stage II regulatio ns and an analysis of the

## 2 emissions impact of eliminating the Stage II controls. This Technical Support Document (TSD) serves as the analysis of the emissions impact of eliminating Stage II requirements
from the St. Louis area. It demonstrates that removal of State II controls will not adversely affect the air quality in the St. L ouis area and satisfies all Clean Air Act (CAA) requirements for removal of control measures from a SIP.

II. Anti-Backsliding Requirements. Section 110(l) of the CAA prohib its revision of a SIP that woul d interfere with attainment of a NAAQS, reasonable further progress towa rd attainment of a NAAQS, or any other applicable requirement of the CAA.

Furthermore, section 193 of the CAA prohibi ts modification of any control requirement in effect before November 15, 1990 in a current nonattainment area, unless the modification insures equivalent or greater emissions reductions.

The Stage II vapor recovery program in St. Louis was established in 1987, therefore the requirements of CAA sections 110(l) and 193 mu st be satisfied before removing Stage II
controls in the St. Louis area.

III. Demonstration.
A. EPA Guidance. On August 7, 2012, EPA released guidance for st ates that wish to remove Stage II requirements from their SIP titled Guidance on Removing Stage II Gasoline Vapor Control Programs from Stat e Implementation Plans and Assessing Comparable Measures , herein referred to as “the EPA guidance.” This guidance presents the methodology and information needed for a state to conduct an emissions inventory analysis related to phasing out an existing Stage II program.

To comply with CAA section 193 requi rements, the EPA guidance recommends comparing the net Stage II efficiency to the net ORVR efficiency and presents an equation to calculate the difference between the two efficiencies.

To comply with CAA section 110(l ) requirements, the EPA guidance recommends computing the incremen tal emission control from Stage II installations as ORVR technology is phased into the motor vehicle fleet. This
incremental emission control is calculated using an equation presented in the EPA guidance.

The EPA guidance also presents a method to quantify the impa ct on the area-wide VOC emissions inventory from the increm ental emissions that result from the removal of Stage II vapor recovery systems.

B. Input Parameters for the Equa tions in EPA’s Guidance Document. The equations in the EPA guidance requi re appropriate area-specific values for the penetration of the ORVR in the moto r vehicle fleet; in-use efficiencies of ORVR and Stage II systems; the proporti on of gasoline disp ensed by facilities

## 3 equipped with Stage II contro ls; the projected gasoline consumption for the area and time periods of interest; and the unc ontrolled displacement refueling emission
factor.

The values of the individual parameters for the St. Louis area are:

1. Penetration of ORVR in the Motor Vehicle Fleet, Q ORVR 

## . Q ORVR 

## represents the proportion of a nnual gallons of highway motor gasoline dispensed to ORVR-equipped vehicles.

Table A-1 of the EPA guidance, replicated in Appendix A, shows nationwide values for the percen tage of ORVR-equipped vehicles (Column 2), the percentage of vehi cle miles traveled by ORVR-equipped vehicles (Column 3), and the percen tage of gasoline dispensed into ORVR-equipped vehicles (Column 4). As stated in section 3.3.3 of the EPA guidance, the nationwide values in Table A-1 may be adjusted to obtain area-specific values by compari ng the area-specific fleet age to the national fleet age.

A comparison of the age distribution of the St. Louis area’s gasoline motor vehicle fleet, presented in Appendix B, to that of the national gasoline motor vehicle fleet, presented in Appe ndix C, shows them to be almost identical. The average age of passenger cars in the St. Louis fleet is just 0.1 years older than the na tional fleet. The averag e age of tier 1 light-duty trucks (gross vehicle weight ra ting less than 6,000 pounds) is 1.1 years
newer in St. Louis than the national fl eet. The average age of tier 2 lightduty trucks (gross vehicle wei ght rating between 6,000 pounds and 8500 pounds) is 1.4 years newer in St. Loui s than the national fleet. The average age of heavy-duty vehicles in St. Louis is 0.2 years older than the nation, but this slight difference is more than offset by the newer age of light-duty trucks, since light -duty trucks are more than thirteen times more numerous than heavy-duty vehicles in the St. Lo uis fleet. The difference in the average age for motorcycles is irrelevant, since motorcycles are not required to have ORVR systems.

Given the similarity in the age distri butions of the St. Louis fleet and the nationwide fleet, the percentage ofgasoline dispensed into ORVRequipped vehicles for the national fleet presented in Table A-1 of the EPA guidance would be a conservative indi cator of the percen tage of gasoline dispensed into ORVR-equipped vehi cles for the St. Louis fleet.

2. In-use control efficiency of ORVR, 

## η ORVR 

## . 

## η ORVR 

## represents the in-use control effi ciency of ORVR systems. Section 3.3.3 of the EPA guidance recommends using 98% for this control efficiency.

## 4 3. In-use control efficiency of Stage II vapor recovery systems, 

## η iuSII 

## . 

## η iuSII 

## represents the in-use control effi ciency of Stage II vapor recovery systems when applied to vehicles that are not equipped with ORVR. Section 3.3.3 of the EPA guidance reco mmends using a value consistent with field test data and advises ag ainst relying on prior EPA guidance, new system certification efficiency, or state regulation claims regarding efficiency. Since Missouri’s inspec tion of Stage II-equipped installations
does not include calculation of in-use efficiency, ot her test data must be used to establish the control efficiency.

In May 2000, the San Diego Air Polluti on Control District released their report titled Performance of Balance Vapor Recovery Systems at Gasoline Dispensing Facilities . They studied balance vapor recovery systems in
four air districts in California a nd used field tests and engineering
calculations to estimate the in-use e fficiency. Their re port concluded that
“American vacuum assist and balan ce vapor recovery systems averaged about 75% overall, with balance sy stems having the worst performance with efficiencies ranging from 63 to 68%.” All Stage II vapor recovery systems in St. Louis are of the bala nce type and their in-use control efficiency is assumed to be 65%, whic h is approximately the middle of the range reported by the San Diego Air Pollution Control District.

4. Proportion of gasoline throughput covered by Stage II vapor recovery systems, Q SII 

## . Q SII 

## represents the proportion of gasoline throughput dispensed by gasoline distribution facilities with Stage II vapor recovery systems. Section 3.3.3 of the EPA guidance r ecommends using the threshold for Stage II applicability to determine this proportion. The default values are 90% for states adopting the CAA exemption provisions and 95% to 97% for states that used a throughput of 10,000 gallons per month for all gasoline dispensing facilities.

Paragraph (1)(C)4. of Mi ssouri rule 10 CSR 10-5.220 Control of Petroleum Liquid Storage, Loading and Transfer sets 10,000 gallons per month as the applicability threshol d for the Stage II vapor recovery requirements at gasoline dispensing f acilities in the St. Louis area. Therefore, per section 3.3.3 of th e EPA guidance, the recommended proportion of gasoline throughput dispen sed by facilities with Stage II vapor recovery systems is assumed to be 96%, which is the middle of the range presented in the EPA guidance.

5. Projected gasoline consumption fo r the area and time periods of interest, GC. GC represents the projected ozone se ason gasoline consumption for the St. Louis area for the years analyzed in this demonstration. Section 3.5.1 of the EPA guidance suggests using th e Federal Highway Administration

## 5 (FHA) to establish the baseline consumption for 2010 and then applying a nationwide growth factor derived fr om the U.S. Department of Energy (DOE) in their national annual forecast of future gasoline consumption.

Table 1 summarizes the calculations for the projected St. Louis ozoneseason gasoline consumption through 2020.

2010 9.02 --- 82,697,384,000 2 642,062,489 3
2011 9.09 0.0078 83,339,159,707 647,045,236 2012 9.33 0.0264 85,539,533,561 664,128,939 2013 9.38 0.0054 85,997,944,780 667,688,043 2014 9.39 0.0011 86,089,627,024 668,399,864 2015 9.40 0.0011 86,181,309,268 669,111,685 2016 9.42 0.0021 86,364,673,756 670,535,327 2017 9.36 -0.0064 85,814,580,293 666,264,401 2018 9.29 -0.0075 85,172,804,585 661,281,655 2019 9.24 -0.0054 84,714,393,366 657,722,550 2020 9.19 -0.0054 84,255,982,146 654,163,445 Table 1 GC, Projected Ozone Season Gasoline Consumption for St. Louis

(million barrels per day) 1 Calculated
Growth Factor (gallons) Motor Gasoline Ozone Season

Nationwide

Gasoline Comsumption (gallons) Year GC, Ozone
Season St.
Louis Gasoline Consumption

1 

## U.S. Department of Energy's Na tional Annual Forecasts of gasoline

consumption. Projected consumption of Motor Gasoline for 2010 through 2020. http://www.eia.gov/oiaf/aeo/table browser/#release=AEO2011&subject=
0-AEO2011&table=11-AEO2011& region=0-0&cases=ref2011-
d020911a

2 

## National Highway Administration. Total national gasoline consumption

for April through October of 2010. http://www.fhwa.dot.gov/policyinfor mation/statistics/2010/33ga.cfm

3 

## Gasoline consumption for St. Loui s is 0.7764% of gasoline consumption

for the 50 States, per Table A-4 of the EPA guidance.

Using the monthly nationwide gasolin e consumption data for 2010 from the FHA report and adding the consumption for the months of April through October gives the 2010 nati onwide gasoline consumption for Missouri’s ozone season. The DOE repor t was used to calculate an annual growth factor for the national gasoline consumption for 2011 through 2020 by subtracting the previous yea r’s consumption from the current year’s consumption and dividing that difference by the previous year’s consumption. The growth factor is then applied to the ozone-season

## 6 national gasoline consumption to project the consumption for 2011 through 2020. As stated in Table A- 4 of the EPA guidance, the Missouri portion of the St. Louis ozone nona ttainment area accounts for 0.7764% of the nationwide gasoline consumption, which allows the St. Louis ozoneseason gasoline consumption to be se parated from the nationwide gasoline consumption.

6. Uncontrolled Displacement Re fueling Emission Factor, EF. EF represents the uncontrolled disp lacement refueling emission factor. This emission factor depends on the Reid vapor pressure (RVP) of the fuel, the dispensed fuel temperature, and the difference between the tank fuel temperature and the dispensed fuel temperature.

The St. Louis ozone nonattainment area uses federally-controlled Reformulated Gasoline (RFG) throughout the year. This gasoline must meet specific formulation requirement s that are designed to reduce VOC emissions and RFG fuel is not require d to meet a specific RVP. The RVP for motor vehicle gasoline sold during the months of May through September in the Missouri portion of the St. Louis ozone nonattainment area is assumed to be 7.0 pounds per s quare inch (psi) as shown in Table A-7 of the EPA guidance, which is re produced in Appendix D. Table A-7 does not include October, which is the final month of Missouri’s ozone
season. The RVP for October is also assumed to be 7.0 psi, which is a
conservative estimate.

T d 

## is the dispensed fuel temperature a nd is presented in Table A-2 of the EPA Guidance, which is reproduced in Appendix E. The mean temperature for the ozone-season months in Missouri (April through October) is 73.57 oF.

Δ T is the difference between the tank fuel temperature and the dispensed fuel temperature. This value is found in Table A-3 of the EPA guidance, which is reproduced in Appendix F. For April through September, the temperature difference is 11.7 oF. For October, the temperature difference is -2.4 oF. The weighted average temperature difference for Missouri’s
ozone season is 9.69 oF.

The equation to calculate EF using th e above parameters is presented in section 3.5.1 of the EPA guidance:

EFሺgrams gallonሻ ൌ e ሾ ିଵ.ଶ଻ଽ଼ି଴.଴଴ସଽ ሺ ୼୘ ሻ ା଴.଴ଶ଴ଷ ሺ ୘ ౚ ሻ ା଴.ଵଷଵହ ሺ ୖ୚୔ ሻ ሿ 

## ⁄

Using the above values for RVP, T d 

## , and Δ T, the uncontrolled displacement refueling emission factor, EF, for the St. Louis ozone season is 2.965 grams of VOC per gallon of fuel dispensed.

## 7 C. Section 193 Demonstration. CAA section 193 requirements may be me t by comparing the Stage II control efficiency to the ORVR control effici ency and demonstrating that the ORVR control program provides greater emissi on reduction benefits than the Stage II control program alone. Section 3.3.2 of the EPA guidance recommends using the following equation to compare the tw o (2) emission reduction benefits:

Delta i 

## = (Q SII 

## )( 

# η iuSII 

## ) – (Q SIIva 

## )(CF i 

## ) – (Q ORVRi 

## )( 

# η ORVR 

## )

Where:

 Delta i 

## is the comparison between the Stage II efficiency and the ORVR efficiency for year i;

 Q SII 

## is the fraction of gasoline throughput covered by Stage II vapor recovery systems;

 

# η iuSII 

## is the in-use Stage II control efficiency;

 Q SIIva 

## is the fraction of gasoline throughput covered by traditional vacuum assist Stage II vapor recovery systems;

 CF i 

## is the compatibility factor for the increase in underground storage tank emissions over the normal breathing/emptying loss emissions when using vacuum assist Stage II vapor recovery systems for year i;

 Q ORVRi 

## is the fraction of annual gall ons of highway motor gasoline dispensed to ORVR-equipped ve hicles for year i; and

 

# η ORVR 

## is the ORVR in-use efficiency.

Since none of the Stage II systems in St. Louis are vacuum assist, Q SIIva 

## is zero and the product of Q SIIva 

## and CF i 

## is zero. Therefore, the equation can be simplified to:

Delta i 

## = (Q SII 

## )( 

# η iuSII 

## ) – (Q ORVRi 

## )( 

# η ORVR 

## )

Table 2 shows the calculated Delta for 2012 through 2020 using the parameter
values in section III.B. of this TSD.

## 8 (decimal) (%)

2012 0.960 0.65 0.777 0.98 -0.137 -13.7%
2013 0.960 0.65 0.810 0.98 -0.17 -17.0%
2014 0.960 0.65 0.840 0.98 -0.20 -19.9%
2015 0.960 0.65 0.865 0.98 -0.22 -22.4%
2016 0.960 0.65 0.886 0.98 -0.24 -24.4%
2017 0.960 0.65 0.903 0.98 -0.26 -26.1%
2018 0.960 0.65 0.919 0.98 -0.28 -27.7%
2019 0.960 0.65 0.932 0.98 -0.29 -28.9%
2020 0.960 0.65 0.943 0.98 -0.30 -30.0% Table 2 Comparison of ORVR and Stage II Control Efficiencies

End of: Q SII η iuSII Q ORVR η ORVR Delta



## Negative Delta values indicate that ORVR has greater control efficiency than Stage II systems. Specifically for the years examined, ORVR provides between 13.7% and 30.0% greater emission reducti on benefits than Stage II control systems. This additional emission reducti on benefit for all future years satisfies the requirements of CAA section 193 fo r “equivalent or greater emissions
reductions.”

D. Section 110(l) Demonstration. CAA section 110(l) requirements may be met by calculating the incremental emission control from Stage II systems as ORVR technology is phased in, and demonstrating that any incremental em issions from the removal of Stage II systems will not interfere with attainment , or progress toward attainment, of any air quality standard. Section 3.3.1 of the EPA guidance recommends calculating the incremental emission control for Stage II systems using the following equation:

Increment i 

## = (Q SII 

## )(1-Q ORVRi 

## )( 

# η iuSII 

## ) – (Q SIIva 

## )(CF i 

## )

Where:

 Increment i 

## is the incremental emission control for Stage II systems for year i;

 Q SII 

## is the fraction of gasoline throughput covered by Stage II vapor recovery systems;

 Q ORVRi 

## is the fraction of annual gall ons of highway motor gasoline dispensed to ORVR-equipped vehicles for year i;

 

# η iuSII 

## is the in-use Stage II control efficiency;

 Q SIIva 

## is the fraction of gasoline throughput covered by traditional vacuum assist Stage II vapor recovery systems; and

 CF i 

## is the compatibility factor for the increase in underground storage tank emissions over the normal breathing/emptying loss emissions when using vacuum assist Stage II vapor recovery systems for year i.

## 9 Since none of the Stage II systems in th e St. Louis area are vacuum assist, Q SIIva 

## is zero (0) and th e product of Q SIIva 

## and CF i 

## is zero (0). Therefore, the equation can be simplified to:

Increment i 

## = (Q SII 

## )(1-Q ORVRi 

## )( 

# η iuSII 

## )

Table 3 shows the calculated Incr ement for 2012 through 2020 using the parameter values in section III.B. of this TSD.

(decimal) (%)

2012 0.960 0.777 0.65 0.139 13.9%
2013 0.960 0.810 0.65 0.119 11.9%
2014 0.960 0.840 0.65 0.100 10.0%
2015 0.960 0.865 0.65 0.084 8.4%
2016 0.960 0.886 0.65 0.071 7.1%
2017 0.960 0.903 0.65 0.061 6.1%
2018 0.960 0.919 0.65 0.051 5.1%
2019 0.960 0.932 0.65 0.042 4.2%
2020 0.960 0.943 0.65 0.036 3.6% Table 3 Incremental Emissions Control for Stage II

End of: Q SII Q ORVR η iuSII Increment



## The increment shows that the additional emissions control for Stage II over
ORVR diminishes over time as ORVR becomes more prevalent in the motor
vehicle fleet. The incremental emissions would approach zero as the percentage of ORVR-equipped vehicles approaches 100%.

To quantify the effects of this increm ental emission control for Stage II, the
additional VOC emissions from the remova l of Stage II may be calculated using the equation presented in sect ion 3.5 of the EPA guidance:

Tons i 

## = (Increment i 

## )(GC i 

## )(EF)

Where:

 Tons i 

## is the overall effect of rem oving Stage II (tons) for year i;

 Increment i 

## is the incremental emissions gain from removal of Stage II systems for year i;

 GC i 

## is the projected gasoline consum ption (gallons) for year i; and

 EF is the uncontrolled displacement refueling emission factor (grams/gallon).

Table 4 shows the calculated tons of VOC emissions per ozone-season day using the parameter values from section III.B. of this TSD.

## 10 (decimal) (gallons) (grams/ gallon) (tons/ozone season) (tons/ozone season day)
2012 0.139 664,128,939 302.0 1.4 2013 0.119 667,688,043 258.7 1.2 2014 0.100 668,399,864 218.1 1.0 2015 0.084 669,111,685 184.2 0.9 2016 0.071 670,535,327 155.9 0.7 2017 0.061 666,264,401 131.8 0.6 2018 0.051 661,281,655 109.2 0.5 2019 0.042 657,722,550 91.2 0.4 2020 0.036 654,163,445 76.0 0.4 2.965 VOC Emissions Table 4 St. Louis Incremental VOC Emissions per Ozone Season Day

End of EF Increment
from Table 3 GC St. Louis Ozone
Season from Table 1



## The VOC emissions calculations include a ppropriate conversion factors for grams to pounds and pounds to tons. The ozone season in Missouri runs from April 1 through October 31, which is 214 days.

As Table 4 illustrates, removal of Stage II vapor recovery systems in the St. Louis area will result in minimal short-term increases in VOC emissions that rapidly
diminish over time. As section 2.2 of th e EPA guidance states, these short-term small emission increases may be consistent with the requirements of CAA section 110(l). A phase-out plan that would re sult in very small foregone emissions
reductions in the near-term that continue to diminish rapidly over time as ORVR phase-in continues may result in tempor ary increases that are too small to interfere with attainment or progr ess toward attainment of a NAAQS.

To demonstrate noninterference of these s hort-term increases with progress of the
St. Louis area toward attainment of the ozone NAAQS, the increases in VOC emissions from phase-out of Stage II will be compared to the mobile VOC
emissions in the St. Louis area. This demonstration shows that the short term increases from the removal of Stage II are much smaller than the decreases in mobile source emissions and, therefore, do not affect the overall downward trend
in mobile source VOC emissions.

The on-road vehicle VOC emissions fo r 2008 were estimated for a previous rulemaking using EPA’s Motor Vehicle Emission Simulator (MOVES) 2010a.
The on-road mobile source emissions for 2015, 2017, and 2022 were calculated using MOVES 2010b and applying a 1.5% a nnual growth fact or to the 2008 vehicle miles traveled and source ty pe population data. The 2011 mobile
emissions were calculated for the purposes of the 2011 National Emissions Inventory using MOVES 2010b. The years 2008, 2011, 2015, 2017, and 2022 were chosen because these years are cu rrently being studied by the Missouri Department of Natural Resources’ Air Qu ality Planning Section for various other SIP actions and the use of these years re duced the modeling resources required for

## 11 this demonstration. Version 2010b of MOVE S is an update to version 2010a that
increases the software’s f unctionality without signifi cantly affecting the modeled emissions of criteria pollutants. EP A considers versions 2010a and 2010b to be the same model for SIP development purposes. Additional details regarding the development of the on-road mobile sour ce VOC emissions inventories used in this demonstration can be found in Appendix G.

The nonroad vehicle emissions were proj ected for the same years using the
NONROAD2008a model and do not include the aircraft, commercial marine vessel, and railroad locomotive source cat egories. Additional details regarding the development of the nonroad mobile so urce VOC emissions inventories used in this demonstration can be found in Appendix H.

The modeled mobile VOC emissions are shown in Table 5.

Onroad Non-road Total Mobile (tons per ozone

season day) (tons per ozone season day) (tons per ozone season day)

2008 60.9 44.1 105.0

2011 36.2 38.0 74.2

2015 32.7 29.5 62.2

2017 27.5 27.8 55.2

2022 20.9 26.7 47.6 Table 5
Modeled Mobile VOC Emissions

Year



## Federal and state mobile source regulati ons have resulted in significant VOC
emission reductions over the 2008-2022 time period covered by this analysis. In particular, the federal Tier 2 tailpipe emission standards, which apply to all passenger cars and light truc ks starting in 2004, have generated substantial VOC
reductions as the overall fleet turns over to these newer, cleaner vehicles. State measures include cleaner-burning reformul ated gasoline and the Gateway Vehicle Inspection Program, which ensures vehicle emission control systems function properly.

To facilitate discussion of the mobile source VOC emissions for any year of interest in this demonstration, a cubic regression curve was fit to the modeled emissions in Table 5. The regression equation is:

y ൌ െ0.0457x ଷ 

## ൅ 276.41x ଶ 

## െ 557629x ൅ 374991576

where y is the predicted mobile source VOC emissions for year x. The values for
the coefficients and constant are rounde d for convenience. The coefficient of determination for the regression is 0. 995, indicating a very close agreement between actual and predicted values. A review of the residuals (the difference between the observed and predicted va lues) shows them to be randomly
distributed with a sum that is close to zero, which indicates th at a cubic regression

## 12 is appropriate for the data. The dom ain of the regression equation is [2008, 2022], meaning the regressi on equation is only valid for the years 2008 through 2022 and predictions should only be made in this timeframe.

Figure 1 shows the modeled mobile emissions from Table 5 and the cubic regression curve.

y = ‐ 0.0457x 3 

### + 276.41x 2



### ‐ 557629x + 4E+08 R2 = 0.9946 0.0 20.0 40.0 60.0 80.0 100.0 120.0

2008 2010 2012 2014 2016 2018 2020 2022 Mobile VOC

Emissions (tons per ozone

season day)

Year 

# Figure 1

Modeled Regression Curve



## Table 6 shows the predicted mobile VOC emi ssions for all years of interest in this demonstration using the regression e quation with unrounded values for the coefficients and constant. These predicted values will allow interpolation of mobile VOC emissions for years included in this demonstration but not actually modeled. Following proper statistical prac tices, all predictions are made within the bounds of the observed (modeled) values used to establish the regression equation.

Total Mobile (tons per ozone

season day)

2012 69.5

2013 65.1

2014 62.0

2015 59.8

2016 58.2

2017 57.0

2018 56.0

2019 54.8

2020 53.1 Year Table 6
Predicted Mobile VOC Emissions

## 13 Figure 2 shows the modeled mobile source VOC emissions, the regression curve, and the predicted mobile source VOC emissions.

0.0 20.0 40.0 60.0 80.0 100.0 120.0

2008 2010 2012 2014 2016 2018 2020 2022 Mobile VOC

Emissions (tons per ozone

season day)

Year 

# Figure 2

Modeled Predicted Regression Curve



## Table 7 shows the predicted mobile s ource VOC emissions using the regression equation, the yearly decreas e in those emissions, the incremental emissions increase from the removal of Stage II controls, and the overall mobile emissions combined with the incremental increased emissions from Stage II removal. In keeping with proper statistical practices , the predicted mobile source emissions from the regression curve are used fo r 2015 and 2017 to avoid mixing predicted and observed values in the same analysis.

Mobile Projected
VOC Emissions

from Table 6 Mobile Projected
VOC Emissions Yearly Decrease Incremental
VOC Emissions

Increase from

Removal of Stage II from

Table 4 Mobile Projected VOC

Emissions + Incremental

VOC Emissions from

Removal of Stage II (tons per ozone

season day) (tons per ozone season day) (tons per ozone season day) (tons per ozone season day)

2012 69.5 1.4 70.9

2013 65.1 4.4 1.2 66.4

2014 62.0 3.2 1.0 63.0

2015 59.8 2.2 0.9 60.6

2016 58.2 1.6 0.7 58.9

2017 57.0 1.2 0.6 57.6

2018 56.0 1.1 0.5 56.5

2019 54.8 1.2 0.4 55.2

2020 53.1 1.7 0.4 53.5 Table 7

Year Impact of Removal of Stage II Controls on Mobile VOC Emissions

## 14 Figure 3 shows the trend in mobile VOC em issions independent of the removal of Stage II controls (blue curve) and the trend in mobile emissions with the
incremental emissions from the removal of Stage II controls included (red curve).

0 10 20 30 40 50 60 70 80

2012 2014 2016 2018 2020 Mobile Emissions (tons per ozone

season day)

Year 

# Figure 3

Mobile Projected VOC Emissions from Table 6

Mobile Projected VOC Emissions + Incremental VOC Emissions from Removal of Stage II



## An analysis of the trend and decrement of the predicted mobile source emissions shows noninterference with pr ogress of the St. Louis area toward attainment of the ozone NAAQS in two ways.

First, the yearly decrease in VOC emi ssions from mobile sources is always greater than the short-termincrease in VOC emissions due to removal of Stage II
controls. This is evidenced in Tabl e 7 by a comparison be tween the column depicting the projected yearly decrease in mobile VOC emissions and the column depicting the incremental VOC emissions increase from removal of Stage II.

Second, the change in the ove rall downward trend in fu ture VOC emissions from
mobile sources is undetectable when the incremental emissions from the removal of Stage II controls are included.

E. Projected Mobile VOC Emissions in Federally-Approved SIP. The most-recent federally-approved ozone SIP is the Redesignation
Demonstration and Maintenance Plan for the Missouri Portion of the St. Louis Ozone Nonattainment Area. This SIP revision, approved by EPA in May 2003 (68 FR 25418), projected mobile VOC emissions for 2000, 2004, and 2014 as
shown in Table 8.

## 15 Onroad Non-road Total Mobile (tons per ozone

season day) (tons per ozone season day) (tons per ozone season day)

2000 103.79 38.58 142.37

2007 74.46 25.65 100.11

2014 47.14 21.79 68.93 Table 8 Federally-Approved SIP Mobile VOC Emissions

Year



## To maintain consistency with the projected non-road emissions in section III.D. of this TSD, the non-road emissions in Table 8 do not include the aircraft, commercial marine vessel, and railro ad locomotive source categories.

The timeframe in the SIP overlaps the tim eframe in this TSD in years 2013 and 2014. Using interpolation to obtain the 2013 emissions in the SIP, a comparison
of the mobile VOC emissions is shown in Table 9.

Federallyapproved SIP TSD 5 Surplus (tons per ozone

season day) (tons per ozone season day) (tons per ozone season day)

2013 73.38 4 65.1 8.3
2014 68.93 62.0 6.9 Table 9 Comparison of Mobile VOC Emissions

Year

4 

## Interpolating between 2007 and 2014, th e mobile VOC emissions in the SIP

would be 73.38 tons per ozone season day.

5 

## Predicted values from Table 7.

As Table 9 shows, the projected mobile VOC emissions in this TSD for 2013 and
2014 are smaller than the emissions for th e same years in the federally-approved SIP. This surplus is more than the incremental emissions from removal of Stage II, shown in Table 4, and provides furt her evidence, beyond th at presented in section III.D., that removal Stage II controls in the St. Louis area will not interfere with attainment or progress toward atta inment of an air quality standard. Furthermore, mobile source VOC reductions would not be needed to offset the small incremental increases in future SIPs for the St. Louis area, as there is more than enough surplus reduction to jus tify removal of St age II controls.

IV. Conclusion. As shown in section III.C. of this TSD, the emissions reduction benefits from ORVR systems in the motor vehicle fleet are greate r than the emissions reduction benefits from Stage II vapor recovery systems for all years of interest in this demonstration. Therefore, the requirements of section 193 of the CAA ar e satisfied for any year analyzed in the
demonstration.

## 16 Section III.D. of this TSD shows the negligib le impact of the small, short-term VOC emissions increases from Stag e II removal on the ove rall progress of the St. Louis area toward attainment of the ozone NAAQS. A ll short-term emissions increases from the removal of Stage II requirements are smalle r than the reductions in mobile source emissions for the years of interest in the de monstration. In addition, the downward trend
of the mobile source VOC emissions is essentially unchanged if the incremental emissions from the removal of Stage II controls are included. Therefore, the requirements of section 110(l) of the CAA ar e satisfied for any year analyzed in the
demonstration.

In conclusion, this Technical Support Docume nt analyzed the impact on air quality in the St. Louis area by the removal Stage II vapor recovery systems. The analysis was conducted in accordance with EPA guidance and covers the years 2012 through 2020.
All calculations in the TSD were made usi ng parameter values that are nominal or
conservative.

The analysis demonstrates that removal of Stage II controls may begin as early as 2013 without negatively impacting the St. Louis ai r quality or violating the Clean Air Act prohibition on backsliding. The Stage II eq uipment phase-out date depends on many factors that have yet to be determined (e .g., testing, permitting, and other logistical and practical issues). The Air Program will co ntinue to work with the EPA, regulated industry, and other stakeholders to establish a reasonable pha se-out date and process.

## A-1 APPENDIX A

## B-1 APPENDIX B

Age of St. Louis Gasoline Motor Vehicle Fleet

Year Age Model

Year Motorcycle Pass Cars LDT1 LDT2 HDGV

2012 30 1982 0.005849 0.000514 0.000433 0.000221 0.001962

2012 29 1983 0.010773 0.000590 0.000681 0.000405 0.002973

2012 28 1984 0.005904 0.000755 0.000637 0.000609 0.003559

2012 27 1985 0.006665 0.001655 0.001273 0.001188 0.006148

2012 26 1986 0.007971 0.001746 0.001416 0.001563 0.007099

2012 25 1987 0.010692 0.002702 0.002625 0.002483 0.008393

2012 24 1988 0.005196 0.002621 0.002658 0.002658 0.007099

2012 23 1989 0.005468 0.004300 0.005082 0.003659 0.011629

2012 22 1990 0.005169 0.004838 0.004933 0.004170 0.012215

2012 21 1991 0.006883 0.007433 0.006105 0.005810 0.012640

2012 20 1992 0.005740 0.007845 0.007080 0.004669 0.008959

2012 19 1993 0.008515 0.012414 0.009465 0.010819 0.012903

2012 18 1994 0.010746 0.012875 0.010799 0.010832 0.014844

2012 17 1995 0.013766 0.020209 0.018149 0.022610 0.023945

2012 16 1996 0.013548 0.023339 0.016257 0.024642 0.033127

2012 15 1997 0.019534 0.028129 0.021574 0.022874 0.032864

2012 14 1998 0.017602 0.031585 0.027784 0.022934 0.041338

2012 13 1999 0.026063 0.043211 0.042466 0.029621 0.034502

2012 12 2000 0.029409 0.046299 0.041382 0.043546 0.058528

2012 11 2001 0.042142 0.061949 0.057056 0.046400 0.075375

2012 10 2002 0.045161 0.057337 0.055264 0.048624 0.066396

2012 9 2003 0.064423 0.069276 0.077376 0.062033 0.064009

2012 8 2004 0.066464 0.058587 0.065458 0.068759 0.070117

2012 7 2005 0.062111 0.066329 0.074564 0.082155 0.068216

2012 6 2006 0.069837 0.062476 0.078426 0.069376 0.054949

2012 5 2007 0.092064 0.066533 0.073422 0.072218 0.067771

2012 4 2008 0.088255 0.067333 0.067408 0.073934 0.047729

2012 3 2009 0.093914 0.067928 0.066432 0.080430 0.054342

2012 2 2010 0.078869 0.051581 0.041347 0.044662 0.026736

2012 1 2011 0.037789 0.054139 0.050754 0.059060 0.022732

2012 0 2012 0.043475 0.063474 0.071691 0.077035 0.046900

36,757 830,970 447,630 234,763 49,446

8.1 8.1 7.8 7.5 9.8 Average Age Number of vehicles

## C-1 APPENDIX C

Age of National Gasoline Motor Vehicle Fleet

Calendar
Year Age Model Year Motorcycle Pass Cars LDGT1 LDGT2 HDGV

2012 30 1982 0.001966 0.000668 0.002037 0.002037 0.005699

2012 29 1983 0.001689 0.000718 0.002178 0.002178 0.005426

2012 28 1984 0.002310 0.001094 0.003234 0.003234 0.006327

2012 27 1985 0.002585 0.001559 0.004318 0.004318 0.008814

2012 26 1986 0.003071 0.00217 0.004989 0.004989 0.011413

2012 25 1987 0.003696 0.002585 0.006043 0.006043 0.009350

2012 24 1988 0.003741 0.003538 0.007146 0.007146 0.011049

2012 23 1989 0.004419 0.004355 0.007774 0.007774 0.011843

2012 22 1990 0.005962 0.005407 0.008745 0.008745 0.010388

2012 21 1991 0.007355 0.006255 0.008972 0.008972 0.009462

2012 20 1992 0.00929 0.008232 0.011363 0.011363 0.011102

2012 19 1993 0.011102 0.011132 0.014774 0.014774 0.014453

2012 18 1994 0.013623 0.015221 0.018422 0.018422 0.020989

2012 17 1995 0.011840 0.018786 0.020574 0.020574 0.023061

2012 16 1996 0.015718 0.023545 0.024745 0.024745 0.025302

2012 15 1997 0.017935 0.028620 0.028422 0.028422 0.027497

2012 14 1998 0.018745 0.034619 0.034691 0.034691 0.032089

2012 13 1999 0.021968 0.044520 0.039503 0.039503 0.045460

2012 12 2000 0.029065 0.054649 0.047137 0.047137 0.048348

2012 11 2001 0.036410 0.056862 0.051960 0.051960 0.052218

2012 10 2002 0.042963 0.057388 0.056257 0.056257 0.047379

2012 9 2003 0.048226 0.056194 0.061399 0.061399 0.052367

2012 8 2004 0.056980 0.057747 0.066770 0.066770 0.058223

2012 7 2005 0.067163 0.060876 0.070393 0.070393 0.064607

2012 6 2006 0.076695 0.063183 0.068310 0.068310 0.063641

2012 5 2007 0.080950 0.062722 0.068566 0.068566 0.063843

2012 4 2008 0.089568 0.056968 0.046968 0.046968 0.048232

2012 3 2009 0.047643 0.051356 0.037902 0.037902 0.040547

2012 2 2010 0.067916 0.061669 0.054558 0.054558 0.052774

2012 1 2011 0.089591 0.070362 0.059917 0.059918 0.057786

2012 1 2012 0.109815 0.076999 0.061931 0.061930 0.060313

6.9 8.0 8.9 8.9 9.6 Average Age

## D-1 APPENDIX D

## E-1 APPENDIX E

## F-1 APPENDIX F

## G-1 APPENDIX G

Stage II Removal Demonstration – Docume ntation of On-Road Mobile Source
VOC Emissions Calculations in the St. Louis Ozone Nonattainment Area

Section 1: St. Louis Nonattainment Area On-Roa d Mobile Source VOC Emissions Calculations

For this demonstration, on-road mobile source emissions for 2008 were calculated using the EPA’s Motor Vehicle Emissions Simulator (M OVES) version 2010a and the on-road mobile source emissions for 2011, 2015, 2017, and 2022 were calculated using MOVES version 2010b. The inputs to the models for 2015, 2017, and 2022 were developed using 2008 as the base year. Both vehicle miles traveled (VMT) data and so urce type population data for these three years, were grown annually by 1.5% from the 2008 data. The 2011 emissions data was calculated with all MOVES inputs developed independently fr om the 2008 data inputs. The 2011 mobile emissions were calculated for the purposes of the 2011 National Emissions Inventory; however they are displayed in this demons tration in order to provide a br oad range of year s demonstrating
the continual decline of mobile source VOC emissi ons in the St. Louis area. Additional details about the development of the 2011 mobile source VOC emissions can be found in Attachment 1 of Appendix G.

The emissions for 2008 were calculated using 2008 VMT data provided by the East West Gateway Council of Governments. The 2008 VMT data was originally generated from the Missouri Department of Transportation for state- owned roads, and then East-West Gateway used
their Traffic Demand Model to calculate the actual local VMT data for each of the five counties
on the Missouri side of the St. Louis Ozone nonattainment area.

The road type distribution input used in 2008 wa s developed from the National County Database (NCD) to distribute the county level VMT to road type. EPA’s VMT converter workbook was then used to produce MOVES input tables. The sa me road type distributi on data that was used for 2008 was also used for 2015, 2017, and 2022. A vehicle registration distribution for 2008 was originally created for the National Mobile Inventory Model (NMIM) using registration data from Missouri’s Department of Revenue. The ve hicle distribution was converted to a MOVES age distribution table using EPA’s VMT converter workbook. The same age distribution table was used for 2015, 2017, and 2022. The registration da ta was also used to create the MOVES vehicle population input tables for 2008. Vehi cle counts were converted from Mobile 6.2 vehicle classes to MOVES source types using the source type fractions fr om the Source Type Pop Fractions table in EPA’s VMT converter workbook. The meteorology data used for 2008 was developed by EPA from National Weather Service data. The 2008 meteorology data was also used for the projected emissions in 2015, 2017, and 2022. Inspection and Maintenance (I/M) input tables were devel oped to characterize the Gateway Vehicle Inspection Program (the I/M program in place in the St. Louis Ozone nonattainment area). Additional details regarding the development of the I/M inpu t can be found in the I/M input table development protocol in Attachment 2 of Appendix G.

## G-2 MOVES base data was used for all othe r inputs to calcula te the 2008, 2015, 2017, and 2022 mobile source emissions, after reviewing the data to ensure accuracy. The base fuel supply tables in MOVES were used for the runs, as they alre ady took into account th e reformulated gasoline
used in the St. Louis nonattainme nt area. A separate input databa se was created for each county, using county specific data where possible. All of the data used to develop the county database manager inputs for the MOVES runs perf ormed for 2008, 2015, 2017, and 2022, other than the data for county database manager inputs wher e EPA default data was used, can be found in
Section 2 of this document.

The MOVES model runs were set up selecting all available gasoline and diesel fuel vehicle type combinations, all months, days, hours, and all ro ad types. A separate run was set-up for each pollutant and each county. The emissions were post-aggregated to the month level using MOVES. Once the MOVES input tables had b een created, MOVES was ran and all months for each year displayed in this demonstration were selected to create an annual emissions profile. The VOC emissions for the months of April through October were totaled and divided by 214, the number of days in those months, to give average ozone season day VOC emissions for each year in which the emissions were calculated.G-3Section 2: Data Used to Develop the MOVES County Database Manager Inputs for theSt. Louis Nonattainment Area for 2008, 2015, 2017, and2022When using MOVES to calculate the on-road mobile source VOC emissions, default data was used in the county database manager forAverageSpeed Distribution, Fuel Supply, Fuel Formulation, VMT Monthly Distribution, VMT DailyDistribution, and VMT Hourly Distribution input tablesfor all five counties. Meteorology Data, Road Type Distribution, and Age Distribution Inputs are the same for 2008, 2015, 2017, and 2022. For allcounty database manager input tables developed by the Air Program for these four years,the data used to develop the input tables is listed in Tables 1– 24 below.2008 MOVES InputsTable 1 – 2008 Source Type Population (MOVES Inputs for 2008 On-Road Mobile Source VOC Emissions)Source Type Population by CountyYearID SourceTypeName SourceTypeIDFranklin Jefferson St Charles StLouis County St Louis City2008 Motorcycle 11 6,067 13,018 11,151 19,243 31042008 Passenger Car 21 46,568 98,009 144,441 527,148 125,7762008 Passenger Truck 31 45,890.24 82,509.19 110,385.78 303,295.72 59,405.612008 Light Commercial Truck 32 16,768.76 28,420.81 35,913.22 97,845.28 20,194.392008 Refuse Truck 41 8.25 41 35.5 93.5 69.52008Single Unit Short-haulTruck 42 24.75 123 106.5 280.5 208.52008Single Unit Long-haulTruck 43 302.08 541.2 549.04 2,709.24 6612008 Motor Home 51 21.53 19.34 19.44 50.14 16.252008 School Bus 52 813.93 900.99 1,019.79 3,623.55 1,249.22008 Transit Bus 53 61.05 66.99 76.07 270.27 92.62008 Intercity Bus 54 44.26 71.09 82.23 378.69 143.452008Combination Short-haulTruck 61 370.31 324.37 327.86 791.19 247.52008Combination Long-haulTruck 62 306.84 257.02 257.57 544.92 160G-4Table 2 – 2008 Annual VMT by HPMS VehicleType, County, and Year (MOVES Inputs for 2008On-Road Mobile Source VOC Emissions)HPMSBaseYearVMT by CountyHPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St.Louis St. Louis City10 Motorcycles 2008 11,619,323 13,841,651 20,770,584 91,989,970 26,665,06320 Passenger Cars 2008 707,169,172 811,173,607 1,171,243,667 5,115,865,231 1,477,495,62130Other 2 axle-4 tirevehicles 2008 799,130,600 924,394,839 1,342,595,411 5,875,722,138 1,702,465,53340 Buses 2008 4,781,820 5,578,789 8,183,119 35,928,481 10,469,86250 Single Unit Trucks 2008 29,351,955 33,386,793 47,634,481 207,228,073 59,856,11960 Combination Trucks 2008 84,673,330 96,333,716 137,528,782 598,448,609 173,536,046G-5Table 3 – 2008 Inspection and Maintenance Data (MOVES Inputs for 2008 On-Road Mobile Source VOC Emissions)PolProcessIDStateIDYearIDSourceTypeIDFuelType IDIMProgramIDInspect FreqTestStandardsIDBegModelYearIDEndModelYearIDUseIMY/NCompliance Factor101 29 2008 21 1 1 1 11 1971 1995 N 93.12101 29 2008 21 1 10 2 51 1996 2006 Y 97.94101 29 2008 31 1 1 1 11 1971 1995 N 93.12101 29 2008 31 1 10 2 51 1996 2006 Y 92.06101 29 2008 32 1 1 1 11 1971 1995 N 93.12101 29 2008 32 1 10 2 51 1996 2006 Y 86.18102 29 2008 21 1 1 1 11 1971 1995 N 93.12102 29 2008 21 1 10 2 51 1996 2006 Y 97.94102 29 2008 31 1 1 1 11 1971 1995 N 93.12102 29 2008 31 1 10 2 51 1996 2006 Y 92.06102 29 2008 32 1 1 1 11 1971 1995 N 93.12102 29 2008 32 1 10 2 51 1996 2006 Y 86.18112 29 2008 21 1 7 1 41 1971 1995 N 93.12112 29 2008 21 1 8 2 43 1996 2006 Y 97.94112 29 2008 31 1 7 1 41 1971 1995 N 93.12112 29 2008 31 1 8 2 43 1996 2006 Y 92.06112 29 2008 32 1 7 1 41 1971 1995 N 93.12112 29 2008 32 1 8 2 43 1996 2006 Y 86.18113 29 2008 21 1 7 1 41 1971 1995 N 93.12113 29 2008 21 1 8 2 43 1996 2006 Y 97.94113 29 2008 31 1 7 1 41 1971 1995 N 93.12113 29 2008 31 1 8 2 43 1996 2006 Y 92.06113 29 2008 32 1 7 1 41 1971 1995 N 93.12113 29 2008 32 1 8 2 43 1996 2006 Y 86.18G-62015 MOVES InputsTable 4 – 2015 Source Type Population (MOVES Inputs for 2015 On-Road Mobile Source VOC Emissions)Source Type Population by CountyYearID SourceTypeName SourceTypeIDFranklin Jefferson St CharlesSt LouisCounty St Louis City2015 Motorcycle 11 6,733 14,448 12,376 21,357 3,4452015 Passenger Car 21 51,683 108,775 160,307 585,053 139,5922015 Passenger Truck 31 50,931 91,572 122,511 336,611 65,9312015 Light Commercial Truck 32 18,611 31,543 39,858 108,593 22,4132015 Refuse Truck 41 9 46 39 104 772015Single Unit Short-haulTruck 42 28 137 118 311 2312015Single Unit Long-haulTruck 43 335 601 609 3,007 7342015 Motor Home 51 24 21 22 56 182015 School Bus 52 903 1,000 1,132 4,022 1,3862015 Transit Bus 53 68 74 84 300 1032015 Intercity Bus 54 49 79 91 420 1592015Combination Short-haulTruck 61 411 360 364 878 2752015Combination Long-haulTruck 62 341 285 286 605 178G-7Table 5 – 2015 Annual VMT by HPMS VehicleType, County, and Year (MOVES Inputs for 2015On-Road Mobile Source VOC Emissions)HPMSBaseYearVMT by CountyHPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St.Louis St. Louis City10 Motorcycles 2015 12,895,647 15,362,086 23,052,127 102,094,600 29,594,08520 Passenger Cars 2015 784,848,108 900,276,901 1,299,898,826 5,677,817,002 1,639,790,99930Other 2 axle-4 tirevehicles 2015 886,911,031 1,025,934,909 1,490,072,687 6,521,140,324 1,889,472,71140 Buses 2015 5,307,079 6,191,590 9,081,993 39,875,042 11,619,92350 Single Unit Trucks 2015 32,576,118 37,054,162 52,866,886 229,991,023 66,431,00960 Combination Trucks 2015 93,974,265 106,915,484 152,635,619 664,185,145 192,598,098G-8Table 6 – 2015 Inspection and Maintenance Data (MOVES Inputs for 2015 On-Road Mobile Source VOC Emissions)PolProcessIDStateIDYearIDSourceTypeIDFuelType IDIMProgramIDInspect FreqTestStandardsIDBegModelYearIDEndModelYearIDUseIMY/NCompliance Factor101 29 2015 21 1 1 1 11 1971 1995 N 93.12101 29 2015 21 1 10 2 51 1996 2013 Y 97.94101 29 2015 31 1 1 1 11 1971 1995 N 93.12101 29 2015 31 1 10 2 51 1996 2013 Y 92.06101 29 2015 32 1 1 1 11 1971 1995 N 93.12101 29 2015 32 1 10 2 51 1996 2013 Y 86.18102 29 2015 21 1 1 1 11 1971 1995 N 93.12102 29 2015 21 1 10 2 51 1996 2013 Y 97.94102 29 2015 31 1 1 1 11 1971 1995 N 93.12102 29 2015 31 1 10 2 51 1996 2013 Y 92.06102 29 2015 32 1 1 1 11 1971 1995 N 93.12102 29 2015 32 1 10 2 51 1996 2013 Y 86.18112 29 2015 21 1 7 1 41 1971 1995 N 93.12112 29 2015 21 1 8 2 43 1996 2013 Y 97.94112 29 2015 31 1 7 1 41 1971 1995 N 93.12112 29 2015 31 1 8 2 43 1996 2013 Y 92.06112 29 2015 32 1 7 1 41 1971 1995 N 93.12112 29 2015 32 1 8 2 43 1996 2013 Y 86.18113 29 2015 21 1 7 1 41 1971 1995 N 93.12113 29 2015 21 1 8 2 43 1996 2013 Y 97.94113 29 2015 31 1 7 1 41 1971 1995 N 93.12113 29 2015 31 1 8 2 43 1996 2013 Y 92.06113 29 2015 32 1 7 1 41 1971 1995 N 93.12113 29 2015 32 1 8 2 43 1996 2013 Y 86.18G-92017 MOVES InputsTable 7 – 2017 Source Type Population (MOVES Inputs for 2017 On-Road Mobile Source VOC Emissions)Source Type Population by CountyYearID SourceTypeName SourceTypeIDFranklin Jefferson St Charles StLouis County St Louis City2017 Motorcycle 11 6,937 14,885 12,750 22,002 3,5492017 Passenger Car 21 53,245 112,063 165,152 602,736 143,8112017 Passenger Truck 31 52,470 94,340 126,214 346,785 67,9242017 Light Commercial Truck 32 19,174 32,496 41,063 111,875 23,0902017 Refuse Truck 41 9 47 41 107 792017Single Unit Short-haulTruck 42 29 141 122 321 2382017Single Unit Long-haulTruck 43 345 619 628 3,098 7562017 Motor Home 51 25 22 22 57 192017 School Bus 52 931 1,030 1,166 4,143 1,4282017 Transit Bus 53 70 77 87 309 1062017 Intercity Bus 54 50 81 94 433 1642017Combination Short-haulTruck 61 423 371 375 905 2832017Combination Long-haulTruck 62 351 294 295 623 183G-10Table 8 – 2017 Annual VMT by HPMS VehicleType, County, and Year (MOVES Inputs for 2017On-Road Mobile Source VOC Emissions)HPMSBaseYearVMT by CountyHPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St.Louis St. Louis City10 Motorcycles 2017 13285,417 15,826,405 23,748,877 105,180,410 30,488,56620 Passenger Cars 2017 808,570,142 927,487,770 1,339,188,268 5,849,429,021 1,689,353,68230Other 2 axle-4 tirevehicles 2017 913,717,917 1,056,943,792 1,535,110,134 6,718,241,791 1,946,582,02440 Buses 2017 5,467,485 6,378,731 9,356,496 41,080,266 11,971,13550 Single Unit Trucks 2017 33,560,731 38,174,124 54,464,788 236,942,502 68,438,88660 Combination Trucks 2017 96,814,637 110,147,005 157,249,031 684,260,141 198,419,375G-11Table 9 – 2017 Inspection and Maintenance Data (MOVES Inputs for 2017 On-Road Mobile Source VOC Emissions)PolProcessIDStateIDYearIDSourceTypeIDFuelType IDIMProgramIDInspect FreqTestStandardsIDBegModelYearIDEndModelYearIDUseIMY/NCompliance Factor101 29 2017 21 1 1 1 11 1971 1995 N 93.12101 29 2017 21 1 10 2 51 1996 2015 Y 97.94101 29 2017 31 1 1 1 11 1971 1995 N 93.12101 29 2017 31 1 10 2 51 1996 2015 Y 92.06101 29 2017 32 1 1 1 11 1971 1995 N 93.12101 29 2017 32 1 10 2 51 1996 2015 Y 86.18102 29 2017 21 1 1 1 11 1971 1995 N 93.12102 29 2017 21 1 10 2 51 1996 2015 Y 97.94102 29 2017 31 1 1 1 11 1971 1995 N 93.12102 29 2017 31 1 10 2 51 1996 2015 Y 92.06102 29 2017 32 1 1 1 11 1971 1995 N 93.12102 29 2017 32 1 10 2 51 1996 2015 Y 86.18112 29 2017 21 1 7 1 41 1971 1995 N 93.12112 29 2017 21 1 8 2 43 1996 2015 Y 97.94112 29 2017 31 1 7 1 41 1971 1995 N 93.12112 29 2017 31 1 8 2 43 1996 2015 Y 92.06112 29 2017 32 1 7 1 41 1971 1995 N 93.12112 29 2017 32 1 8 2 43 1996 2015 Y 86.18113 29 2017 21 1 7 1 41 1971 1995 N 93.12113 29 2017 21 1 8 2 43 1996 2015 Y 97.94113 29 2017 31 1 7 1 41 1971 1995 N 93.12113 29 2017 31 1 8 2 43 1996 2015 Y 92.06113 29 2017 32 1 7 1 41 1971 1995 N 93.12113 29 2017 32 1 8 2 43 1996 2015 Y 86.18G-122022 MOVES InputsTable 10 – 2022 Source Type Population (MOVES Inputs for 2022 On-Road Mobile Source VOC Emissions)Source Type Population by CountyYearID Source Type NameSource TypeID Franklin Jefferson St CharlesSt Louis County St Louis City2022 Motorcycle 11 7,473 16,035 13,735 23,703 3,8232022 Passenger Car 21 57,360 120,723 177,916 649,318 154,9252022 Passenger Truck 31 56,525 101,631 135,968 373,586 73,1732022 Light Commercial Truck 32 20,655 35,007 44,236 120,521 24,8752022 Refuse Truck 41 10 51 44 115 862022Single Unit Short-haulTruck 42 31 152 131 346 2572022Single Unit Long-haulTruck 43 372 667 676 3,337 8142022 Motor Home 51 27 24 24 62 202022 School Bus 52 1,003 1,110 1,256 4,463 1,5392022 Transit Bus 53 75 83 94 333 1142022 Intercity Bus 54 54 88 101 466 1772022Combination Short-haulTruck 61 456 400 404 975 3052022Combination Long-haulTruck 62 378 317 317 671 197G-13Table 11 – 2022 Annual VMT by HPMS VehicleType, County, and Year (MOVES Inputs for 2022On-Road Mobile Source VOC Emissions)HPMS Base Year VMT by CountyHPMS VtypeID HPMS Vtype NameYearID Franklin Jefferson St. CharlesSt. LouisCounty St. Louis City10 Motorcycles 2022 14,312,168 17,049,533 25,584,286 113,309,173 32,844,84420 Passenger Cars 2022 871,059,680 999,167,739 1,442,686,099 6,301,496,316 1,819,913,69830Other 2 axle-4 tirevehicles 2022 984,333,696 1,138,628,640 1,653,749,592 7,237,454,415 2,097,021,67740 Buses 2022 5,890,034 6,871,705 10,079,604 44,255,113 12,896,31350 Single Unit Trucks 2022 36,154,439 41,124,373 58,674,045 255,254,367 73,728,11860 Combination Trucks 2022 104,296,860 118,659,606 169,401,866 737,142,504 213,754,019G-14Table 12 – 2022 Inspection and Maintenance Data (MOVESInputs for 2022 On-Road Mobile Source VOC Emissions)PolProcessIDStateIDYearIDSourceTypeIDFuelType IDIMProgramIDInspect FreqTestStandardsIDBegModelYearIDEndModelYearIDUseIMY/NCompliance Factor101 29 2022 21 1 1 1 11 1971 1995 N 93.12101 29 2022 21 1 10 2 51 1996 2020 Y 97.94101 29 2022 31 1 1 1 11 1971 1995 N 93.12101 29 2022 31 1 10 2 51 1996 2020 Y 92.06101 29 2022 32 1 1 1 11 1971 1995 N 93.12101 29 2022 32 1 10 2 51 1996 2020 Y 86.18102 29 2022 21 1 1 1 11 1971 1995 N 93.12102 29 2022 21 1 10 2 51 1996 2020 Y 97.94102 29 2022 31 1 1 1 11 1971 1995 N 93.12102 29 2022 31 1 10 2 51 1996 2020 Y 92.06102 29 2022 32 1 1 1 11 1971 1995 N 93.12102 29 2022 32 1 10 2 51 1996 2020 Y 86.18112 29 2022 21 1 7 1 41 1971 1995 N 93.12112 29 2022 21 1 8 2 43 1996 2020 Y 97.94112 29 2022 31 1 7 1 41 1971 1995 N 93.12112 29 2022 31 1 8 2 43 1996 2020 Y 92.06112 29 2022 32 1 7 1 41 1971 1995 N 93.12112 29 2022 32 1 8 2 43 1996 2020 Y 86.18113 29 2022 21 1 7 1 41 1971 1995 N 93.12113 29 2022 21 1 8 2 43 1996 2020 Y 97.94113 29 2022 31 1 7 1 41 1971 1995 N 93.12113 29 2022 31 1 8 2 43 1996 2020 Y 92.06113 29 2022 32 1 7 1 41 1971 1995 N 93.12113 29 2022 32 1 8 2 43 1996 2020 Y 86.18

## G-15 MOVES Inputs Used for 2008, 2015, 2017, and 2022

Table 13 – Road Type Distribu tion (MOVES Inputs for 2008, 2015, 2017, and 2022 On-Road Mobile Source VOC Emissions)
Source Type ID Road Type ID Road Type
VMT Fraction
51 3 0.015096
51 4 0.473646
51 5 0.509786
52 1 0
52 2 0.001464
52 3 0.015054
52 4 0.458621
52 5 0.524861
53 1 0
53 2 0.001465
53 3 0.015061
53 4 0.460904
53 5 0.52257
54 1 0
54 2 0.001459
54 3 0.015026
54 4 0.450614
54 5 0.532901
61 1 0
61 2 0.001473
61 3 0.015102
61 4 0.475707
61 5 0.507719
62 1 0
62 2 0.001475
62 3 0.01511
62 4 0.47878
62 5 0.504636 Source Type
ID Road Type ID Road Type
VMT Fraction

11 1 0

11 2 0.00113

11 3 0.011837

11 4 0.460448

11 5 0.526585

21 1 0

21 2 0.001544

21 3 0.015158

21 4 0.459076

21 5 0.524222

31 1 0

31 2 0.001361

31 3 0.01387

31 4 0.46841

31 5 0.516359

32 1 0

32 2 0.001379

32 3 0.014014

32 4 0.467447

32 5 0.51716

41 1 0

41 2 0.001583

41 3 0.015108

41 4 0.496442

41 5 0.486867

42 1 0

42 2 0.001583

42 3 0.015108

42 4 0.496442

42 5 0.486867

43 1 0

43 2 0.001336

43 3 0.013582

43 4 0.495108

43 5 0.489975

51 1 0

51 2 0.001472G-16Table 14 –Vehicle Age Distribution(MOVES Inputs for 2008, 2015, 2017, and 2022 On-Road Mobile Source VOC Emissions)Source Type IDAgeID 11 21 31 32 41 42 43 51 52 53 54 61 620 0.019 0.0248 0.016038 0.015215 0.006 0.006 0.03372 0.019407 0.022549 0.022677 0.024421 0.018826 0.0178341 0.0646 0.0564 0.059034 0.058508 0.0045 0.0045 0.054157 0.048521 0.039325 0.03937 0.032671 0.049995 0.0526132 0.1035 0.0666 0.063189 0.062229 0.0132 0.0132 0.092687 0.158149 0.129508 0.130555 0.106219 0.16227 0.1698353 0.1096 0.0649 0.073971 0.073529 0.0144 0.0144 0.057163 0.057986 0.082002 0.084645 0.091592 0.052692 0.044034 0.1172 0.0653 0.081725 0.079405 0.0138 0.0138 0.098055 0.068814 0.07432 0.076743 0.07138 0.066656 0.0634795 0.0874 0.0632 0.072225 0.07206 0.0291 0.0291 0.05743 0.075516 0.060754 0.062113 0.04642 0.077218 0.0805846 0.0922 0.0633 0.075227 0.075017 0.0378 0.0378 0.060728 0.071294 0.059753 0.061551 0.046468 0.072242 0.0743927 0.0713 0.0679 0.075731 0.074101 0.0258 0.0258 0.034794 0.048222 0.045101 0.04668 0.038418 0.04791 0.0477758 0.061 0.0675 0.069095 0.069315 0.0249 0.0249 0.049567 0.050551 0.053801 0.053336 0.05744 0.050259 0.0496229 0.0435 0.0652 0.059343 0.060606 0.039 0.039 0.065329 0.101607 0.075238 0.074281 0.059218 0.106403 0.11463110 0.036 0.0604 0.056546 0.058019 0.0351 0.0351 0.065952 0.060365 0.052757 0.052173 0.04901 0.061907 0.06448111 0.0255 0.0501 0.045379 0.044021 0.0309 0.0309 0.066337 0.035034 0.038694 0.038608 0.041544 0.03448 0.03347912 0.0208 0.0488 0.040069 0.041299 0.0351 0.0351 0.042714 0.030037 0.038252 0.038379 0.043733 0.028628 0.02617313 0.0189 0.039 0.031719 0.032547 0.083 0.083 0.048635 0.022609 0.033622 0.033505 0.041779 0.020871 0.01776914 0.0171 0.042 0.029341 0.030746 0.0836 0.0836 0.033323 0.026945 0.032499 0.031744 0.038573 0.026434 0.02533115 0.0122 0.0313 0.025132 0.025766 0.0492 0.0492 0.018302 0.014853 0.01522 0.015277 0.015313 0.014766 0.01462616 0.0119 0.0274 0.020261 0.020238 0.0441 0.0441 0.01489 0.014543 0.016624 0.016485 0.018482 0.014281 0.01377817 0.0073 0.0213 0.01591 0.015912 0.0267 0.0267 0.010657 0.011093 0.012019 0.01218 0.012215 0.010861 0.01049118 0.0063 0.0184 0.014002 0.013972 0.0399 0.0399 0.009968 0.011696 0.014667 0.014636 0.016859 0.011229 0.01039419 0.0063 0.0138 0.011117 0.011398 0.0609 0.0609 0.012691 0.012448 0.018417 0.017168 0.026192 0.012123 0.01122120 0.0064 0.0121 0.014109 0.014268 0.0333 0.0333 0.018084 0.014903 0.019136 0.018141 0.024946 0.014734 0.01417221 0.0054 0.0083 0.015761 0.015219 0.0558 0.0558 0.00363 0.01022 0.014831 0.014247 0.019752 0.009773 0.00882922 0.0068 0.0065 0.011686 0.011205 0.054 0.054 0.00501 0.010636 0.017272 0.016478 0.024234 0.009966 0.00857423 0.0097 0.0049 0.00791 0.008124 0.0351 0.0351 0.003627 0.006385 0.007661 0.00744 0.00919 0.006293 0.00607224 0.013837 0.003694 0.00582 0.006825 0.022815 0.022815 0.003017 0.003218 0.003631 0.003569 0.004095 0.003185 0.00310825 0.019738 0.002785 0.004029 0.004856 0.01483 0.01483 0.002668 0.001864 0.001955 0.001889 0.002204 0.001885 0.00190326 0.006525 0.002099 0.002201 0.002308 0.009639 0.009639 0.002379 0.001137 0.001109 0.001082 0.001162 0.001156 0.00118327 0 0.001582 0.001069 0.001073 0.006266 0.006266 0.00214 0.00071 0.000645 0.000647 0.000595 0.000721 0.00073928 0 0.00044 0.000253 0.000245 0.004073 0.004073 0.001953 0.000417 0.000378 0.000362 0.000398 0.000432 0.00045429 0 0 0.000147 0.000139 0.002647 0.002647 0.001784 0.00024 0.000223 0.000197 0.000282 0.000256 0.00027830 0 0 0.001957 0.001836 0.064531 0.064531 0.028609 0.010581 0.018036 0.013841 0.035194 0.011546 0.012147G-17Table 15 – Average Monthly Temperaturesby Hour of the Day for Franklin County in Fahrenheit (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 25.8 29 39.1 48.4 55.9 68.2 70.9 67.1 60.6 49 38.4 24.72 24.8 27.4 37 46.4 54.7 67.1 69.6 66.2 60.8 47.9 38.4 24.73 23.8 26.3 35.8 45 53.6 66 68.8 65.4 60 47.1 37.5 244 22.8 25.3 34.5 44.1 52.6 65 68.1 64.8 59.1 46.5 36.8 23.55 22 24.9 33.5 43.2 51.7 64.1 67.5 63.9 58.6 45.7 36 236 21.4 24.2 32.6 42.7 51.1 63.5 66.8 63.4 58.2 45.1 35.3 22.57 21.2 23.8 32.1 42.7 52.6 65.7 68.2 63.9 57.9 44.6 34.7 22.88 21 23.4 32.4 45.3 56.2 69.3 71.4 67.6 60 45.9 34.2 22.39 22.2 24.9 36.4 48.9 59.6 72.9 75.2 71.7 63.8 50.9 37.1 23.810 26.6 27.8 40.5 52.5 63.2 76.2 78.5 75.7 67.8 56 41.5 27.411 31.2 31.1 44.7 55.7 66.4 79 81.3 78.9 71.4 60.5 45.6 31.712 36 34.3 48.5 58.5 68.8 81.3 83.6 81.2 74.4 63.9 49.3 36.113 39.6 37.2 51.7 61.5 70.6 83 85.6 82.9 76.5 66.1 51.9 39.714 42.4 39.5 53.9 63.3 72.1 84.3 87 84.1 77.9 67.5 54 42.215 44 41 55.6 64.9 73.6 85.1 88 84.9 78.7 68.4 55.1 43.916 44.4 41.6 56.3 65.8 74.3 85.5 88.1 85.1 78.7 68.5 55.1 44.117 43.2 41.4 56.1 65.6 74.3 85.2 87.7 84.7 77.9 67.4 53.7 42.218 39.4 39.9 54.8 64.6 73.3 84.1 86.7 83.3 75.8 64.2 50.1 37.819 35.2 37 51.7 62.1 71.3 82.3 84.6 80.4 71.3 58.9 46.8 34.420 32.8 34.9 47.9 58.2 67.3 79 81 75.9 67 55.9 44.8 3221 31 33.6 45.7 55.6 63.2 74.6 76.9 72.5 65.1 54.1 43.1 30.122 29.6 32.2 43.9 53.4 60.7 72.2 75 70.6 63.8 52.7 41.9 28.423 28.2 30.9 42.3 51.5 58.9 70.7 73.4 69.2 62.5 51.3 40.7 27.124 27.2 29.9 40.5 50 57.2 69.3 72.1 68.1 61.4 50.2 39.5 25.7G-18Table 16 – Average Monthly Percent Relative Humidity by Hour of the Day forFranklin County (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 68.3 76 71.8 70.6 77 78.3 83.9 86.1 88.2 77 68.9 69.92 69 77.2 72.8 72.9 77.2 80.2 84.4 86.9 88.5 78.7 70.3 71.83 70.1 78 73.9 74.5 78.2 81.6 85.3 87.5 89.2 79.8 71.7 72.94 70.9 78.3 75.3 75.3 79.3 82.4 86.1 88.1 90.1 80.4 72.8 73.85 71.8 78.3 76.8 76.1 80.5 83.8 86.4 89.3 90.4 81.6 73.9 75.16 72.3 78.9 77.6 77 81.1 84.4 87.3 89.6 90.4 82.5 75 75.77 72 78.8 78.2 77.6 80.3 83 85.8 89 90.4 83.4 75.9 76.18 72 78.8 78.3 74.5 76.2 77.9 81.4 84.9 89.5 83.2 76.5 769 71.2 77.6 74.8 69.8 71.5 72.4 74.9 77.5 84.7 76.8 74.3 75.210 66.9 74.3 69.7 64.8 65.8 66.9 69.3 70.2 77.2 67.7 68.4 72.411 62 70.4 63.5 61.1 61.1 62.1 64.5 64.2 70.5 59.4 62.1 68.412 56.8 67 58.7 58.2 58.1 58.2 60.9 60 64.6 53.3 56.5 64.813 53 63.8 54.8 55 56.3 55.4 57.9 57.2 60.9 49.9 52.7 62.114 50.2 61.5 52.6 53 55.1 53.7 55.8 55.4 58.3 47.7 49.4 60.215 48.4 60 51 51.1 53.1 52.2 54.6 54.2 56.8 46.3 47.6 58.716 47.3 59.4 50.7 49.7 52.5 51.5 54.4 54 56.6 46 47.1 5817 47.9 59.8 50.7 49.1 51.7 51.5 55.1 54.9 58.1 47.2 48.4 59.218 51.2 61.6 52.5 49.9 52.1 52.8 56.7 57.6 62.8 52.3 52.9 62.919 55.5 65.4 56.2 52.8 54.6 55.5 61.1 63.5 72.5 61.5 57.2 65.620 58.3 68.2 61 57.5 60.3 61.6 68.4 72.7 80.5 66.9 60 6721 60.6 70.1 63.9 60.8 66.3 68.8 75.3 78.4 83.9 69.6 62.5 67.622 62.8 72 66.3 63.9 70.3 72.8 78.3 81.9 85.3 71.9 64.4 68.323 64.5 73.7 68.2 66.4 73.1 75 80.7 83.8 86.4 73.7 65.9 68.724 66.1 75.1 70.3 68.3 75.4 77 82.3 85.2 87.6 75.6 67.6 69.1G-19Table 17 – Average Monthly Temperatures by Hour of theDay for Jefferson County in Fahrenheit (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 25.6 28.3 38.5 47.4 55 68.3 70.1 67 60.2 48.6 37.5 24.22 24.7 26.8 36.3 45.5 53.8 67.3 68.8 66.1 60.4 47.7 37.3 24.23 23.7 25.7 35.2 44.3 52.8 66.3 68.1 65.3 59.5 46.9 36.4 23.24 22.5 24.8 34.2 43.3 51.8 65.2 67.5 64.6 58.9 46.3 35.8 22.85 22 24.2 33.3 42.6 50.9 64.5 66.8 63.9 58.2 45.4 35 22.36 21.2 23.5 32.3 42.3 50.5 63.8 66.2 63.4 57.9 44.8 34.3 21.87 20.8 23.1 31.8 42.3 52.1 66 67.6 63.9 57.6 44.3 33.7 22.18 20.8 22.9 32 44.9 55.7 69.6 70.8 67.6 59.9 45.6 33.5 21.69 22 24.2 35.7 48.4 58.9 73 74.5 71.6 63.7 50.7 36.6 23.210 26.2 27 39.5 51.7 62.4 76.3 77.6 75.6 67.6 55.8 41 2711 30.7 30 43.6 54.7 65.5 78.9 80.3 78.7 71.3 60.2 45 3112 35 33.2 47.1 57.1 67.7 81.1 82.5 80.8 74.2 63.7 48.6 35.213 38.3 35.7 50.1 59.7 69.3 82.8 84.3 82.5 76.4 65.8 51.1 38.814 41.2 37.9 52.3 61.6 70.4 83.9 85.6 83.7 77.7 67.2 53.2 41.115 42.9 39.2 53.7 62.9 71.7 84.6 86.6 84.4 78.5 68.1 54.3 42.816 43.3 40 54.5 63.8 72.6 84.9 86.9 84.4 78.6 68.1 54.3 4317 42.1 39.8 54.3 63.5 72.6 84.6 86.5 84.2 77.8 67.1 52.9 41.118 38.5 38.3 53 62.6 71.6 83.6 85.4 82.7 75.6 63.9 49.1 36.919 34.4 35.7 50 60.1 69.7 81.8 83.4 79.9 71 58.7 45.7 33.820 32 33.6 46.8 56.8 65.8 78.6 79.9 75.6 66.7 55.6 43.7 31.521 30.3 32.1 44.6 54.1 62 74.4 76.1 72.3 64.7 53.7 41.9 29.822 29.1 31.2 42.7 52.2 59.7 72.2 74.1 70.4 63.3 52.3 40.7 27.923 28 29.9 41.4 50.3 57.6 70.7 72.6 69 62.1 50.9 39.5 26.824 27 29.1 39.7 48.9 56.2 69.4 71.3 68.1 61.1 49.7 38.4 25.1G-20Table 18 – Average Monthly Percent Relative Humidity by Hour of the Day forJefferson County (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 67.9 75.6 72.4 70.8 76.6 76.7 83 85.5 87.6 77.2 68.8 69.62 69 77.1 73 73.1 76.8 78.3 83.8 86.6 87.6 78.3 70.2 71.13 70.1 78 74.1 74.4 77.6 79.9 84.6 86.9 88.5 80.1 71.3 72.54 71.2 78.2 75.2 75.5 78.7 81.2 85.2 87.8 88.8 80.7 72.1 73.15 71.8 78.2 76.1 76.1 79.5 82.3 85.8 88.4 89.4 81.9 73.2 74.46 72.3 78.8 77.6 76.9 80.1 83.2 86.3 88.7 89.4 82.8 74.3 757 72.6 78.8 78.2 77.3 79.3 81.3 85.2 88.4 89.4 83.4 75.2 75.38 72.3 78.4 78.5 73.9 75 76 80.5 84 88.2 83.2 75.5 75.69 71.1 77.2 75.4 69 70.7 70.4 73.8 76.7 83.2 77.1 73.4 74.810 67.1 74.2 70.2 64.4 65 64.8 68.5 69.4 76.1 67.5 67.5 71.711 62.2 70.5 64.4 60.9 60.3 60.1 63.7 63.8 69.5 58.9 61.3 6812 57.2 67.1 59.9 58.5 57.6 56.1 60 59.5 63.9 52.9 56.2 64.613 53.7 64.7 56.4 55.6 56.1 53 57.4 56.9 60 49.3 52.6 6214 50.9 62.1 54.1 53.4 54.8 51.8 55 55.1 57.9 46.8 49.5 59.815 48.8 60.8 53 51.6 53.4 50.2 53.7 54.1 56.4 45.5 47.7 58.316 47.7 59.9 52.5 50.1 52.4 49.5 53.5 54.1 56 45.4 47 57.917 48.1 60.1 52.7 49.7 52 49.5 53.9 54.8 57.5 46.4 48.3 5918 51.3 61.6 54.4 50.7 52.1 50.5 55.6 57.6 62.3 51.7 52.9 62.719 55.6 65.2 58.2 54 54.5 53.5 59.7 63.5 71.7 61 57.3 65.320 58.2 68.3 62.5 58.4 60.3 59.2 67.1 71.6 79.3 66.7 59.9 66.621 60.5 70.2 65.3 61.8 66.2 66.5 73.7 77.6 82.9 69.6 62.9 67.322 62.5 71.9 67.5 64.5 70 70.6 77.2 81 84.6 71.8 64.5 68.223 64.2 73.6 69.5 67.3 73.2 72.7 79.5 83.2 85.8 73.7 66.3 68.424 65.8 74.7 71.3 68.7 75.3 74.9 81.1 84.3 86.7 75.8 67.8 69.1G-21Table 19 – Average Monthly Temperaturesby Hour of the Day for St. Charles County in Fahrenheit (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 24.3 26.9 37.9 47.5 54.9 68.8 70.2 67.6 60.6 49.2 37.6 23.32 23.3 25.3 36.1 45.7 53.7 67.8 69 66.8 60.7 48.1 37.5 23.53 22.2 24.1 34.9 44.4 52.6 66.7 68.3 65.9 59.9 47.6 36.6 22.84 21.2 23.2 33.8 43.5 51.5 65.7 67.9 65.1 59.2 46.8 35.9 225 20.7 22.9 32.8 42.7 50.8 64.8 67.2 64.5 58.6 46 35 21.56 20.3 22.4 31.7 42.4 50.2 64.3 66.7 63.9 58.1 45.4 34.2 21.37 20.1 21.8 31.2 42.4 51.9 66.4 68 64.5 58 44.8 33.8 218 20.1 21.5 31.5 45 55.3 69.8 71 68 60.1 46.1 33.5 20.59 21.4 23.1 35.2 48.4 58.2 73 74.4 71.9 63.7 50.8 36.5 22.310 25.8 25.6 38.9 51.4 61.8 75.9 77.5 75.7 67.6 55.4 40.5 2611 30.3 28.6 42.7 54.3 64.7 78.4 79.9 78.7 71.3 59.7 44.2 30.312 34.4 31.7 46.2 56.7 66.7 80.8 82.2 80.7 74.1 63.1 47.9 34.813 38 34.1 48.9 59.3 68 82.3 84.1 82.2 76.2 65 50.5 38.314 40.7 36.2 51 61.1 69.4 83.3 85.4 83.5 77.6 66.4 52.6 40.315 42 37.6 52.4 62.5 70.8 84 86.4 84.1 78.3 67.3 53.8 41.816 42 38.1 52.9 63.4 71.7 84.4 86.5 84.3 78.4 67.4 53.8 42.117 41.1 37.8 52.7 63.3 71.8 84.3 86 84 77.8 66.3 52.5 40.618 37.5 36.4 51.6 62.4 71 83.3 85 82.7 75.7 63.3 48.9 36.319 33.3 33.6 48.8 60.1 69.1 81.8 83 79.8 71 58.4 45.8 33.320 30.9 31.9 45.4 56.5 65.3 78.6 79.7 75.8 66.8 55.4 43.9 3121 29 30.5 43.5 54 61.5 74.6 76 72.5 65 53.9 42.5 29.322 27.8 29.5 41.9 52.3 59.1 72.5 74 70.7 63.4 52.6 41.4 27.323 26.5 28.2 40.8 50.5 57.4 71.1 72.7 69.4 62.4 51.4 40 25.824 25.4 27.7 39 49.1 56 69.8 71.3 68.5 61.2 50.3 38.8 24.3G-22Table 20 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Charles County (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 67.5 75.8 71.7 70.5 76.6 77.3 83.3 85.5 87.9 76.1 68.8 69.82 68.2 77 72.1 72.8 76.5 78.9 84.1 86.4 88.2 77.8 70.2 71.33 69.6 77.5 73.5 74.4 77.9 80.5 84.9 86.9 88.8 78.9 71.6 72.54 70.7 78.1 74.9 75.3 79.3 82.1 85.2 88.1 89.4 79.5 72.4 73.45 71.6 78.1 76.4 75.8 79.8 82.9 86.4 88.4 90.1 81 73.8 74.96 71.9 78 77.5 76.3 81 84.1 86.7 89 90.4 81.9 75.3 75.67 71.6 78.7 78.2 77 79.9 81.9 85.2 88.1 90 83.1 76.2 76.58 71.6 78.3 78.2 73 75.5 76.3 80.2 84 88.8 82.6 76.4 76.29 70.5 76.7 74.7 67.9 71.4 70.6 73.8 76.5 83.8 76.8 73.9 7510 66.2 73.8 69.8 63.9 64.7 65.5 68.2 69 76.3 67.9 68.3 72.211 61.3 70.1 63.8 60.2 59.8 60.5 63.5 62.9 69.2 59.8 62.4 68.512 56.4 66.7 58.8 57.5 57 55.9 59.5 58.5 63.9 53.4 56.9 65.413 52.5 64 55.1 54.7 55.9 53.1 56.6 55.9 59.8 49.9 53.2 62.714 49.9 61.3 53 52.7 54.3 51.7 54.4 54 57.3 47.6 49.8 61.215 48.1 59.5 51.6 50.9 52.7 50.1 53.1 52.9 56 46.3 47.8 59.616 47.1 58.9 51.4 49.5 51.7 49.2 52.9 53 55.6 46 47.1 59.217 47.3 59.5 51.8 49.1 50.8 49.2 53.8 53.9 57.1 47 48.6 60.218 50.9 61.1 53.5 50.3 50.7 50.3 55.5 56.4 61.6 52.2 53.3 6419 55.7 65.2 57.5 53.3 53.1 53.2 60 62.4 71.9 61 57.6 66.620 58.6 68.1 62.3 58.2 59 59.3 66.8 71.2 80.5 66.9 60.4 67.721 61.1 70.6 64.9 61.5 65.4 66.9 74 77.6 83.5 69.3 62.2 67.822 62.6 72.3 67.1 63.7 70.2 71.1 77.4 81.3 85.6 71.1 63.9 68.123 64 73.7 68.6 66.6 72.9 73.5 79.2 83.3 86.1 72.9 65.5 68.524 65.6 74.9 70.7 68.2 75 76 81.1 84.7 87.6 74.7 67.3 69.3G-23Table 21 – Average Monthly Temperaturesby Hour of the Day for St. Louis County in Fahrenheit (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 25.5 28.1 39 48.2 56.2 70.2 71.8 68.8 62.4 50.7 38.8 24.42 24.5 26.6 37.3 46.2 55 69.1 70.6 68.1 62.5 49.8 38.6 24.63 23.6 25.2 36.1 45.1 53.8 68 69.9 67.2 61.6 49.1 37.8 23.94 22.7 24.5 35.1 44.3 52.8 67 69.6 66.5 60.9 48.4 37 23.25 21.9 23.9 34.2 43.6 52.1 66.1 68.9 65.9 60.4 47.6 36.3 22.56 21.4 23.4 33.1 43.3 51.6 65.6 68.4 65.3 59.9 47.1 35.6 22.57 21.2 23.1 32.6 43.3 53.2 67.7 69.7 65.8 59.8 46.6 35 22.58 21.2 22.7 32.9 45.7 56.5 70.9 72.5 69.4 61.9 47.9 34.9 229 22.5 24.1 36.4 48.9 59.4 73.9 75.7 72.8 65.2 52.2 37.8 23.910 26.6 26.7 39.8 51.8 62.5 76.8 78.5 76.6 68.7 56.7 41.5 27.211 30.8 29.5 43.3 54.6 65.2 79.3 81 79.5 72.2 60.7 45.1 31.112 34.9 32.5 46.7 56.8 67.1 81.6 83.1 81.4 74.8 63.9 48.4 35.113 38.2 35 49.4 59.3 68.4 83.1 84.8 83 76.8 65.8 50.9 38.714 41 37.1 51.3 61 69.4 84 86.2 84.1 78.3 67.2 52.8 40.815 42.5 38.5 52.7 62.4 70.8 84.8 87.2 84.8 79 67.9 54 4216 42.5 39 53 63.2 71.6 85 87.3 84.9 79 68.1 54.1 42.517 41.6 38.6 53 63.1 71.9 84.9 86.8 84.6 78.4 67 52.8 40.818 38.1 37.2 51.7 62.4 70.9 84 85.9 83.2 76.3 64.2 49.5 3719 34.2 34.6 49.1 60.1 69.3 82.5 83.9 80.5 72.3 59.9 46.6 34.420 31.8 32.9 46.3 56.8 65.6 79.5 80.7 76.8 68.5 57.1 44.8 32.321 30.1 31.6 44.4 54.4 62.5 76 77.4 73.9 66.6 55.5 43.4 30.622 29.2 30.8 42.6 52.8 60.2 73.9 75.8 72.1 65.2 54.1 42.2 28.423 27.9 29.5 41.7 51 58.4 72.4 74.4 70.8 64.1 52.9 41.1 2724 26.8 28.8 40 49.6 57.2 71.2 73 69.8 63.1 51.7 39.9 25.3G-24Table 22 – Average Monthly Percent Relative Humidity by Hour of the Day forSt. Louis County (MOVES Inputs for 2008, 2015,2017, and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 67.3 75.9 71.8 70 75.9 75.8 82.3 85 87.4 75.9 68.9 70.22 68.1 77.1 72.2 72.6 76 78.1 83.3 85.8 87.7 77.6 70.3 71.83 69.5 78.3 73.3 74.2 77.4 80 84.2 86.7 88.6 79.1 71.7 72.94 70.3 78.5 74.4 74.7 78.5 81.3 84.7 87 89.5 79.6 72.5 73.85 71.5 78.5 75.9 75.6 79.3 82.4 85.9 87.9 89.8 81.1 73.6 75.76 72 78.8 77.7 76.1 80.5 83.3 86.2 88.4 90.1 82 75.4 76.47 71.7 79.1 78 76.4 79.4 81.1 84.7 88.2 90.1 82.9 76.3 76.78 71.4 78.4 78.6 72.5 75 75.6 79.8 83.2 88.6 82.4 76.6 76.69 70.3 77.2 74.8 67.9 71 70 73.4 76.3 83.3 76.7 74.1 75.210 66 74.2 69.9 63.7 65 64.7 67.9 68.6 76.2 67.6 68.2 72.711 61.4 70.5 64.6 60.2 60 60 63.2 62.8 69.1 59.4 62.3 68.912 56.7 67.1 59.6 57.8 57.5 55.2 59.2 58.4 63.5 53.1 57.5 6613 52.8 64.6 56 54.9 56.4 52.3 56.3 55.8 59.6 49.5 53.4 63.214 49.8 62 53.9 53.1 55.1 51.3 54.2 53.9 57 47.2 50.4 61.215 47.8 59.9 52.4 51.3 53.5 49.5 52.5 52.9 55.5 45.9 48.4 59.916 46.8 59 52.7 49.9 52.7 48.6 52.5 52.9 55.3 45.5 47.5 59.217 47.2 59.7 52.9 49.6 51.4 48.6 53.2 53.9 56.8 46.6 48.8 60.518 50.6 61.2 54.8 50.5 51.4 49.7 54.7 56.4 61.5 51.4 53.2 64.119 55.1 65.1 58.5 54 53.5 52.4 58.9 62 70.6 59.1 57.2 66.520 58.2 68.2 62.5 58.2 59 57.9 65.8 69.8 78.6 65.1 60 67.921 60.2 70.4 65.3 61.4 64.5 64.3 72.3 76.1 82.2 68.2 62.1 68.322 61.9 72.1 67.7 63.6 69.2 69 75.5 80 84.2 70.4 64 68.623 63.7 73.8 69.3 66.6 72.5 71.6 77.7 82.2 85.3 72.5 65.7 6924 65.2 75 71.1 68.3 74.6 74.3 80.1 83.9 86.5 74.6 67.4 69.7G-25Table 23 – Average Monthly Temperaturesby Hour of the Day for St. Louis City in Fahrenheit (MOVES Inputs for 2008, 2015, 2017,and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 25.9 28.9 40.2 48.1 56 70.1 72.4 69.2 62.7 51.5 39.4 25.92 25 27.5 38.4 46.2 54.9 69.1 71.2 68.5 62.9 50.7 39.2 25.93 24 26.3 37.4 45.3 53.8 68 70.6 67.7 62.2 49.9 38.3 254 22.9 25.4 36.3 44.3 52.9 67 70.1 67 61.5 49.4 37.8 24.65 22.4 24.9 35.6 43.7 52.2 66.2 69.6 66.3 61 48.6 37.1 23.96 21.7 24.4 34.5 43.4 51.8 65.6 69.1 65.9 60.6 47.9 36.4 23.97 21.5 23.8 33.9 43.7 53.6 67.9 70.6 66.5 60.5 47.5 35.8 23.98 21.3 23.5 34.2 46 57 71.2 73.5 70.2 62.6 48.8 35.8 23.29 22.8 24.9 37.7 49.2 59.8 74.4 76.5 73.7 66 53.3 38.7 25.210 27 27.5 41 52.1 62.9 77.4 79.2 77.5 69.5 57.8 42.5 28.411 31 30.3 44.3 54.8 65.6 79.9 81.6 80.3 72.9 61.8 45.9 3212 35 33 47.4 57 67.7 82.1 83.6 82.3 75.4 64.8 49.3 35.913 38.1 35.5 50.1 59.3 68.7 83.8 85.2 83.7 77.3 66.8 51.7 39.314 41.1 37.4 51.8 61 69.7 84.5 86.7 84.9 78.7 68.1 53.5 41.515 42.7 38.8 53.3 62.4 71.1 85.3 87.6 85.5 79.4 68.8 54.6 42.916 42.5 39.3 53.6 63.2 71.7 85.4 87.8 85.5 79.5 68.8 54.6 42.917 41.6 39.1 53.4 62.9 72 85.4 87.5 85.3 78.7 67.9 53.3 41.518 38.1 37.7 52.2 62.1 71.2 84.4 86.4 83.8 76.8 65.1 50 37.719 34.3 35.1 49.5 60.1 69.4 82.9 84.5 81.2 72.5 60.7 47.2 3520 32.1 33.4 47 56.7 65.8 79.8 81.4 77.2 68.5 57.8 45.2 33.421 30.4 32.2 45 54.5 62.5 76 77.9 74.3 66.8 56.2 43.8 31.622 29.5 31.3 43.5 52.8 60.2 73.6 76.2 72.3 65.5 54.9 42.7 29.823 28.3 30.1 42.6 51 58.3 72.2 74.8 71.2 64.3 53.6 41.6 28.424 27.2 29.6 41.1 49.5 57.1 71 73.6 70.3 63.4 52.4 40.6 26.8G-26Table 24 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Louis City (MOVES Inputs for 2008, 2015, 2017,and 2022 On-Road Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 68 76.6 72.6 71.4 77 76.6 83.4 85.9 87.7 76.9 69.3 69.82 69 78.1 73.2 73.8 76.9 78.7 84.2 86.5 87.7 78 71 71.33 69.8 79 74 74.8 78 80.8 85.4 87 88 79.7 72.1 72.74 70.9 79 75.2 75.9 79.1 81.9 85.6 87.6 88.9 80.3 72.3 73.65 72.1 78.9 76.3 76.5 79.9 82.7 86.5 88.5 89.5 81.5 73.4 75.26 72.4 79.2 78.4 77.4 80.5 83.9 86.8 88.5 89.8 82.7 75.2 75.87 72.7 79.5 79 77.1 79.4 81.7 85.1 88.2 89.5 83.3 76.3 76.28 72.3 79.1 79.4 73.4 75.1 75.9 80.1 83.3 88.3 83.1 76.3 76.49 70.9 77.9 75.6 68.3 71 70 74 76.4 83 77 73.6 7510 66.7 74.9 70.6 64.2 64.8 64.5 68.4 68.9 75.7 67.4 68 72.511 61.9 71.5 65.5 60.7 60.1 59.6 63.7 63.1 68.9 59.1 62.4 6912 57.4 68.3 60.7 58.5 57.1 55.3 59.7 58.7 63.6 52.8 57.2 66.113 53.7 65.5 57 55.7 56.4 52 57.1 56.3 59.7 48.9 53.8 63.114 50.6 63.3 55.1 53.7 55.1 51.2 54.6 54.2 57 46.4 50.7 61.115 48.4 61.4 53.4 51.7 53.7 49.5 53.1 53.5 55.5 45.5 48.5 59.516 47.8 60.3 53.4 50.4 52.9 48.9 52.7 53.5 55.1 45.3 47.8 59.117 48 60.7 53.8 50.2 51.8 48.9 53.4 54.2 56.8 46.4 48.9 60.118 51.2 62.1 55.8 51.4 51.4 49.9 55.2 57.1 61.6 51.3 53.3 63.619 55.9 66 59.7 54.8 53.9 52.4 59.2 62.6 71.1 59.4 57.3 66.220 58.7 69.2 63.6 59.6 59.7 58.2 66.3 71.1 79.7 65.7 60.6 67.521 60.8 71.1 66.4 62.1 65.5 65 73.6 77.5 83.4 68.8 62.6 68.422 62.5 73.1 68.7 64.8 70 70.2 76.8 81.4 84.8 71 64.5 68.723 64.3 74.8 70.2 67.7 73.6 72.8 79.1 83.1 86.2 73.1 66.3 68.924 66.1 75.7 71.8 69.4 75.7 75.3 81 84.8 87.1 75.5 67.8 69.6

## G-27 Attachment 1 of Appendix G

Documentation of On-Road Mobile Source VOC Emissions Calculations in the
St. Louis Ozone Nonattainment Area for 2011

Section 1: St. Louis Area On-Road Mobile Source VOC Emissions Calculations for 2011

The 2011 on-road mobile source emissions invent ory data used in this demonstration was
calculated with MOVES 2010b. The 2011 mobile emi ssions were calculated for the purposes of
the 2011 National Emissions Inventor y; however they are displaye d in this demonstration in order to provide a broad range of years demonstr ating the continual dec line of mobile source
VOC emissions in the St. Louis area.

The emissions for 2011 were calculated with MOVES 2010b, using 2011 VMT data provided by the East West Gateway Council of Governments. The 2011 VMT data was originally generated from the Missouri Department of Transportati on for state-owned roads, and then East-West Gateway used their Traffic Demand Model to calcu late the actual local VMT data for each of the
five counties on the Missouri side of the St. Louis Ozone nonattainment area.

The road type distribution input used in 2011 was developed from Missouri Department of Transportation traffic distribution data for state-owned roads. Th e road type distribution is an average of all five counties. The Source Type Population and Age Distribution tables were developed using 2011 motor vehicle registration data from the Misso uri Department of Revenue.
The list of vehicle identificati on numbers provided by the Missouri Department of Revenue was
converted into Mobile6 vehicle cl assifications using a contractor to decode the VINs. The EPA provided excel conversion tables were used to convert the Mobile6 age distribution and vehicle population numbers into the MOVES formatted age distribution and source type population tables. The meteorology data used for 2011 wa s developed by EPA from National Weather Service data. The data was provided in the 2011 NEI MOVES County Database files, and each county has county specific meteorology data. Inspection and Maintenance (I/M) input tables were developed to characterize the Gateway Ve hicle Inspection Program (the I/M program in place in the St. Louis Ozone nonatt ainment area). Add itional details regarding the development of the I/M input can be found in the I/M input table development prot ocol (Attachment #2).

MOVES 2010b base data was used for all othe r inputs to calculate the 2011 mobile source emissions, after reviewing the data to ensure ac curacy. The base fuel supply tables in MOVES were used for the runs, as they already took into account the reformulated gasoline used in the St. Louis nonattainment area. A separate input data base was created for each county, using county specific data where possible. All of the data used to develop th e county database manager inputs for the MOVES 2010b runs performed for 2011, other than the data for county database manager inputs where EPA default data was used, can be found in Section 2 of this document.

The MOVES model runs were set up selecting all available gasoline and diesel fuel vehicle type combinations, all months, days, hours, and all ro ad types. A separate run was set-up for each pollutant and each county. The emissions were post-aggregated to the month level using MOVES. Once the MOVES input tables ha d been created, MOVES 2010b was ran and all

## G-28 months for 2011 were selected to create an annua l emissions profile. The VOC emissions for the months of April through October were totaled an d divided by 214, the number of days in those months, to give average ozone season day VOC emissions for 2011

.G-29Section 2: Data Used to Develop the MOVES County Database Manager Inputs for the St. Louis Nonattainment Area Counties for 2011When using MOVES 2010b to calculate the on-road mobile source VOCemissions, default data was usedin the county database manager forAverage Speed Distribution, Fuel Supply, FuelFormulation, VMT Monthly Distribution, VMT Daily Distribution, and VMT Hourly Distribution forall five counties. For all county database manager input tables developed bythe Air Program for 2011, the data used to develop these input tables islisted in Tables 1 – 15 below.Table 1 – 2011 Source Type Population (MOVES Inputs for 2011 On-Road Mobile Source VOC Emissions)Source Type Population by CountyYearID SourceTypeName SourceTypeIDFranklin Jefferson St Charles StLouis County St Louis City2011 Motorcycle 11 3,350 7,286 8,742 14,883 2,4972011 Passenger Car 21 37,614 82,976 143,363 472,093 98,1062011 Passenger Truck 31 41,668 76,955 112,323 287,935 51,5252011 Light Commercial Truck 32 15,143 26,379 36,070 91,906 17,4142011 Refuse Truck 41 12 44 36 74 282011Single Unit Short-haulTruck 42 35 131 108 222 832011Single Unit Long-haulTruck 43 258 490 504 1,994 3222011 Motor Home 51 20 17 16 45 152011 School Bus 52 668 737 820 2,846 9622011 Transit Bus 53 50 55 60 214 722011 Intercity Bus 54 38 61 73 299 1102011Combination Short-haulTruck 61 335 280 270 679 2312011Combination Long-haulTruck 62 276 219 210 456 151G-30Table 2 – 2011 Annual VMT by HPMS VehicleType, County, and Year (MOVES Inputs for 2011On-Road Mobile Source VOC Emissions)HPMSBaseYearVMT by CountyHPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St.Louis St. Louis City10 Motorcycles 2011 9,402,897 14,491,095 24,790,826 80,646,379 20,723,45820 Passenger Cars 2011 665,926,569 1,026,279,979 1,755,721,576 5,711,491,339 1,467,664,80630Other 2 axle-4 tirevehicles 2011 255,497,009 393,754,323 673,620,235 2,191,336,137 563,101,07740 Buses 2011 4,851,597 7,476,945 12,791,280 41,610,973 10,692,64750 Single Unit Trucks 2011 43,124,442 66,460,408 113,697,992 369,867,925 95,043,85260 Combination Trucks 2011 121,423,920 187,130,150 320,135,292 1,041,423,637 267,611,510G-31Table 3 – 2011 Inspection and Maintenance Data (MOVES Inputs for 2011 On-Road Mobile Source VOC Emissions)Pol ProcessIDStateIDYearIDSourceType IDFuelType IDIM ProgramIDInspectFreqTestStandards IDBeg ModelYear IDEnd ModelYear IDUse IMY/NComplianceFactor101 29 2011 21 1 1 1 11 1971 1995 N 93.12101 29 2011 21 1 10 2 51 1996 2009 Y 97.94101 29 2011 31 1 1 1 11 1971 1995 N 93.12101 29 2011 31 1 10 2 51 1996 2009 Y 92.06101 29 2011 32 1 1 1 11 1971 1995 N 93.12101 29 2011 32 1 10 2 51 1996 2009 Y 86.18102 29 2011 21 1 1 1 11 1971 1995 N 93.12102 29 2011 21 1 10 2 51 1996 2009 Y 97.94102 29 2011 31 1 1 1 11 1971 1995 N 93.12102 29 2011 31 1 10 2 51 1996 2009 Y 92.06102 29 2011 32 1 1 1 11 1971 1995 N 93.12102 29 2011 32 1 10 2 51 1996 2009 Y 86.18112 29 2011 21 1 7 1 41 1971 1995 N 93.12112 29 2011 21 1 8 2 43 1996 2009 Y 97.94112 29 2011 31 1 7 1 41 1971 1995 N 93.12112 29 2011 31 1 8 2 43 1996 2009 Y 92.06112 29 2011 32 1 7 1 41 1971 1995 N 93.12112 29 2011 32 1 8 2 43 1996 2009 Y 86.18113 29 2011 21 1 7 1 41 1971 1995 N 93.12113 29 2011 21 1 8 2 43 1996 2009 Y 97.94113 29 2011 31 1 7 1 41 1971 1995 N 93.12113 29 2011 31 1 8 2 43 1996 2009 Y 92.06113 29 2011 32 1 7 1 41 1971 1995 N 93.12113 29 2011 32 1 8 2 43 1996 2009 Y 86.18

## G-32 Table 4 – Road Type Distribution (MOVES Inputs for 2011 On-Road Mobile Source VOC Emissions)

Source Type
ID Road Type ID Road Type
VMT Fraction

11 1 0

11 2 0.017288

11 3 0.074577

11 4 0.616845

11 5 0.29129

21 1 0

21 2 0.017288

21 3 0.074577

21 4 0.616845

21 5 0.29129

31 1 0

31 2 0.017288

31 3 0.074577

31 4 0.616845

31 5 0.29129

32 1 0

32 2 0.017288

32 3 0.074577

32 4 0.616845

32 5 0.29129

41 1 0

41 2 0.017288

41 3 0.074577

41 4 0.616845

41 5 0.29129

42 1 0

42 2 0.017288

42 3 0.074577

42 4 0.616845

42 5 0.29129

43 1 0

43 2 0.017288

43 3 0.074577

43 4 0.616845

43 5 0.29129

51 1 0

51 2 0.017288

51 3 0.074577

51 4 0.616845

51 5 0.29129 Source Type ID Road Type

ID Road Type
VMT Fraction
52 1 0
52 2 0.017288
52 3 0.074577
52 4 0.616845
52 5 0.29129
53 1 0
53 2 0.017288
53 3 0.074577
53 4 0.616845
53 5 0.29129
54 1 0
54 2 0.017288
54 3 0.074577
54 4 0.616845
54 5 0.29129
61 1 0
61 2 0.017288
61 3 0.074577
61 4 0.616845
61 5 0.29129
62 1 0
62 2 0.017288
62 3 0.074577
62 4 0.616845
62 5 0.29129G-33Table 5 –Vehicle Age Distribution (MOVES Inputsfor 2011 On-Road Mobile Source VOC Emissions)Source Type IDAgeID 11 21 31 32 41 42 43 51 52 53 54 61 620 0.0436 0.0639 0.076398 0.074052 0.0348 0.0348 0.013131 0.059681 0.068461 0.06768 0.077126 0.058628 0.0565721 0.0379 0.0545 0.056036 0.052896 0.0246 0.0246 0.003494 0.034957 0.035371 0.036001 0.033854 0.034558 0.0340192 0.0789 0.0518 0.038122 0.037103 0.0132 0.0132 0.036216 0.033113 0.035872 0.035904 0.037791 0.032638 0.0318093 0.094 0.0677 0.066376 0.066571 0.0184 0.0184 0.069138 0.047342 0.047587 0.047801 0.047158 0.047186 0.046974 0.0883 0.0671 0.060881 0.060684 0.0405 0.0405 0.098013 0.136686 0.128434 0.129911 0.118171 0.137277 0.1387055 0.0921 0.0667 0.07325 0.0735 0.0369 0.0369 0.056028 0.068436 0.076964 0.077734 0.080941 0.066623 0.0636246 0.0699 0.0625 0.074895 0.073397 0.0231 0.0231 0.102831 0.076632 0.074017 0.075087 0.069021 0.076507 0.0765647 0.0622 0.0663 0.069494 0.069842 0.0504 0.0504 0.120834 0.066117 0.056923 0.057919 0.047356 0.067119 0.0691468 0.0665 0.0586 0.067393 0.067372 0.0575 0.0575 0.078472 0.067755 0.055622 0.056864 0.043202 0.069115 0.0718379 0.0645 0.0693 0.072855 0.071667 0.0255 0.0255 0.040211 0.036375 0.03931 0.040733 0.037322 0.035149 0.03335710 0.0451 0.0572 0.057108 0.058032 0.0306 0.0306 0.047493 0.047575 0.047842 0.047521 0.048973 0.047696 0.04782811 0.0421 0.0618 0.052988 0.05455 0.0423 0.0423 0.066277 0.075638 0.060895 0.060468 0.051416 0.078298 0.0828812 0.0294 0.0462 0.042401 0.044027 0.0287 0.0287 0.036229 0.046378 0.040119 0.039618 0.03702 0.047673 0.04982913 0.026 0.0431 0.037305 0.036396 0.0211 0.0211 0.024733 0.034504 0.030644 0.030445 0.028417 0.035246 0.03650414 0.0176 0.0315 0.027359 0.028988 0.0197 0.0197 0.020917 0.026129 0.032284 0.032271 0.036799 0.025117 0.02332915 0.0195 0.028 0.024189 0.025117 0.0357 0.0357 0.024419 0.019853 0.024916 0.024896 0.028652 0.019026 0.01756316 0.0135 0.0233 0.017828 0.019102 0.0291 0.0291 0.019666 0.021785 0.023893 0.023282 0.027185 0.021759 0.0215517 0.0137 0.0201 0.017869 0.018499 0.0451 0.0451 0.016002 0.014999 0.013556 0.013504 0.012653 0.015267 0.01572518 0.0107 0.0128 0.010756 0.010998 0.0456 0.0456 0.010873 0.012056 0.01322 0.013077 0.014467 0.011942 0.011719 0.0085 0.0124 0.010364 0.010483 0.0282 0.0282 0.008743 0.009118 0.00864 0.008691 0.008141 0.009172 0.00928120 0.0057 0.0078 0.006807 0.006906 0.0527 0.0527 0.008974 0.008864 0.010739 0.010809 0.011895 0.008519 0.00792821 0.0068 0.0074 0.00685 0.007057 0.0644 0.0644 0.014947 0.009824 0.014223 0.013313 0.020052 0.009571 0.00888822 0.0051 0.0048 0.00685 0.006959 0.0367 0.0367 0.016863 0.009534 0.012041 0.011208 0.016262 0.009557 0.00937923 0.0054 0.0042 0.009505 0.00924 0.0616 0.0616 0.002219 0.008127 0.010536 0.009934 0.014029 0.008044 0.0077424 0.005718 0.003675 0.011175 0.010707 0.103394 0.103394 0.00104 0.007278 0.009543 0.008907 0.013027 0.007235 0.00699325 0.006054 0.003216 0.002712 0.002851 0.030206 0.030206 0.000944 0.005649 0.008432 0.007738 0.012466 0.00555 0.00519526 0.00641 0.002814 0.00084 0.000986 0 0 0.000942 0.003298 0.007172 0.006438 0.012116 0.003039 0.00239127 0.006787 0.001296 0.00033 0.000461 0 0 0.00011 0.001451 0.001527 0.001481 0.001711 0.001463 0.00147328 0.007186 0 0.000239 0.000311 0 0 7.60E-05 0.001052 0.001112 0.001089 0.001223 0.001055 0.00105329 0.007609 0 0.00019 0.000219 0 0 4.67E-05 0.000785 0.000832 0.000836 0.000852 0.000775 0.00075830 0.013236 0 0.000635 0.001027 0 0 0.060118 0.009009 0.009272 0.008839 0.010701 0.009196 0.00941G-34Table 6 – Average Monthly Temperatures by Hour of the Day for Franklin County in Fahrenheit(MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 24.7 34.9 44.1 50.3 59.4 68.6 67.7 66.8 60.6 46.1 43.9 26.62 22.2 34.7 42 48.2 57.9 67.7 66.9 66.2 59.6 46.1 42.9 273 21.1 33.3 40.9 47.2 56.8 66.6 65.9 65.4 58.8 45.3 42 26.44 20.2 32.3 40.1 46.1 56 65.8 65.2 64.6 58 44.5 41.3 25.55 19 31 39.4 45.2 55 65.1 64.4 63.8 57.3 43.5 40.6 24.76 18.3 29.8 38.5 44.6 54.2 64.6 63.7 63.1 56.7 42.9 40.2 24.27 17.8 28.6 37.8 44.5 56 66.6 65.3 63.6 56.3 42.1 39.7 23.88 17.4 27.8 38.2 47.9 59.9 70.2 69 67.7 58.9 42.9 39.6 23.49 17.9 29.8 42.2 52.4 63.6 74 72.7 72.3 62.7 46 42.7 2410 21.8 34 46.6 56.2 66.8 77.3 75.7 76.2 66.7 49.3 47.7 27.411 26.1 38.2 50.8 59.8 69.7 80 78.4 79.2 70.4 52.5 51.8 30.812 30.3 42.4 54.6 62.6 72 82.4 80.2 81.6 73.2 55.3 55.3 34.213 33.9 45.6 57.4 64.6 73.8 84.3 81.9 83.4 75.1 57.4 57.9 36.514 36.7 48.4 59.8 66.1 75.5 85.7 83 84.6 76.5 59 59.7 38.215 38.6 50.5 61.2 66.7 76.6 85.9 83.7 85.4 77.3 59.9 60.6 39.116 39.7 51.3 61.8 66.8 76.7 86.2 83.8 85.4 77.4 60.1 60.5 39.317 39.2 51 61.5 66.4 76.3 86.1 83.5 85 76.7 59.3 58.9 37.818 36 48.8 59.6 65.3 75.5 85 82.9 83.7 74.9 57.2 54.9 3419 32.4 44.8 55.9 63.1 73.4 83.1 81.2 80.9 71.1 53.7 51.5 31.920 30.5 42.2 52.1 59.6 69.5 79.9 77.8 76.2 67.1 51.6 49.5 30.421 28.9 40.4 49.8 56.9 66.1 75.6 73.6 72.8 65.4 50.1 48.1 29.322 28 38.7 47.9 54.8 64 73.2 71.4 70.9 63.8 49 46.8 28.723 27 37.2 46.4 53 62.2 71.4 69.9 69.5 62.7 47.9 45.8 28.124 25.7 35.9 45.1 51.4 60.7 69.8 68.6 68 61.6 47.1 44.8 27.2G-35Table 7 – Average Monthly Percent Relative Humidity by Hourof the Day for Franklin County (MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 68.4 68.5 65 69.7 78.7 82 84.3 86.1 83.9 80.7 72.9 75.12 69.9 69 67.4 70 80.7 83.4 84.9 87.2 84.7 81.6 75.2 76.13 70.4 70.3 69.2 71.3 82.1 84.8 86 87.8 85.6 83.2 76.3 76.44 71.3 71.1 70.5 72.6 82.9 86 86.6 88.7 86.5 83.8 77.5 775 72.1 72.8 71.9 73.9 83.8 86.9 87.5 89.6 87.4 84.7 78.7 77.96 72.3 73.6 73 75.1 84.7 87.5 88.1 90.3 88 85 79.2 78.27 72.6 74.1 73.8 75.6 83.3 85.7 87.2 90 88.7 85.6 80.2 78.58 72.9 74.6 74.1 72.8 77.3 79.9 81.5 85.5 86.9 85.3 80.8 78.59 72.9 72.9 69.9 66.5 69.9 73.5 74.7 78.4 81.6 81.6 78.5 77.810 69.6 67.5 63.5 61.4 63.9 68.2 68.7 71.5 74.9 77 71.1 74.611 64.8 62.4 57.8 56.7 58.9 64.4 64 65.9 67.9 71.6 64.7 7012 60 57.3 52.9 53.1 55.3 60.6 60.7 61.7 62.4 67.4 59.4 65.913 56 53.9 48.8 50.8 52.6 58 58.1 58.7 59.2 64.4 55.7 63.514 52.8 50.9 45.6 49 50.4 55.8 56.6 56.4 56.7 62.2 52.7 61.415 50.9 49 43.8 48.2 48.9 55.1 55.7 55 55.2 60.9 51 60.216 49.6 48 42.8 48 48.6 54.6 55.7 54.6 55 60.5 50.8 6017 50.1 48.1 42.6 48.3 49.1 54.5 56.1 55.1 56.3 61.5 52.3 61.618 53.8 50.8 44.7 49 50.4 56.1 57.4 57.3 59.6 65.1 57.3 65.319 58.3 56 48.9 51.8 53.9 59 61 62.7 67.7 70.9 62.4 67.820 61.1 59.4 53.6 56.2 60.8 64.8 67.8 71.2 75.8 74.3 65.2 7021 63.8 62.2 57.2 60.3 67.2 71.9 75.8 77.1 78.4 76.5 66.8 71.122 65.1 64.6 59.8 63.3 71 75.8 79.7 79.9 81.1 77.5 68.8 72.223 66.1 66.3 61.7 66.1 74.2 78.3 81.6 82.1 81.9 78.7 69.8 73.124 67.7 68 63.6 68.2 76.8 80.1 83.5 84.3 83 79.5 71.3 74.6G-36Table 8 – Average Monthly Temperatures by Hour of the Dayfor Jefferson County in Fahrenheit (MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 25 33.3 42.6 49.7 60 69.5 67.9 66.8 61.9 47.2 44.9 27.62 22.6 33.2 40.6 47.8 58.9 68.6 67.3 66.1 61 47.2 44.1 283 21.6 32.2 39.5 46.9 57.9 67.8 66.3 65.3 60.2 46.3 43.4 27.24 20.8 31.2 38.9 45.9 56.9 67 65.6 64.5 59.5 45.8 42.6 26.65 19.9 30 38.3 45.2 56.2 66.3 64.9 63.8 58.8 44.9 42 25.76 18.9 28.7 37.5 44.7 55.3 65.8 64.3 63.3 58.2 44.2 41.7 25.37 18.3 27.5 36.8 44.7 57.2 67.9 65.8 63.8 57.9 43.4 41.3 24.98 17.8 26.7 37.5 47.8 60.6 71.2 69.2 67.7 60.4 44.3 41 24.79 18.4 28.7 41 51.8 64 74.8 72.7 71.9 64 47.2 44.1 25.510 22.1 32.7 45.2 55.3 66.8 77.7 75.5 75.8 68 50.6 48.9 28.711 26 36.6 49 58.5 69.3 80.2 77.9 78.5 71.4 53.7 52.8 3212 29.5 40.5 52.6 61.2 71.2 82.4 79.7 80.7 73.8 56.1 55.9 35.113 32.5 43.6 55.2 62.9 72.7 84 81.4 82.4 75.5 58 58.3 37.414 34.9 46.2 57.2 64.2 74.1 85.2 82.4 83.7 76.8 59.4 60 39.115 36.7 48.1 58.7 64.8 75.1 85.5 82.9 84.4 77.6 60.4 60.9 39.916 37.5 48.9 59.4 64.9 75.2 85.6 83 84.4 77.7 60.6 60.8 40.117 37 48.6 59 64.2 74.7 85.5 82.9 83.7 77.1 59.8 59.1 38.418 34.3 46.6 57.2 63.4 73.8 84.2 82 82.4 75.5 57.7 55.4 34.919 31.3 42.6 53.8 61.4 72.1 82.8 80.6 79.7 71.9 54.3 52.1 32.620 29.5 40.1 50.2 58.2 68.6 79.8 77.5 75.3 68.2 52.5 50.3 31.221 28.2 38.5 47.9 55.8 65.7 76 73.7 72.3 66.5 51.1 49 30.322 27.6 37 46.1 54 63.8 73.8 71.6 70.5 65 50 47.8 29.523 26.8 35.8 44.6 52.3 62.5 72.1 70.1 69.1 63.9 49 46.8 28.924 26 34.5 43.4 50.8 61.1 70.6 68.8 67.7 62.9 48.1 45.8 28.2G-37Table 9 – Average Monthly Percent Relative Humidity by Hourof the Day for Jefferson County (MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 68.8 69.2 65.1 70.2 79.4 81.8 84 85.5 83.3 80.1 73.9 75.22 70.3 69.7 67.2 70.3 80.7 83.2 84.3 86.9 84.5 81.4 75.6 76.23 71.1 70.2 68.8 71.5 82.5 84.3 85.7 87.5 85.1 83.2 76.7 76.84 71.6 71 70.1 72.9 83.6 85.5 86.3 88.4 86 83.2 78.2 77.15 71.9 72.4 71.2 73.9 84.2 86.6 86.9 89.3 86.9 84.1 79.1 786 72.4 73.1 72.3 74.8 85.4 87.2 87.2 89.9 87.5 84.7 79.7 78.37 72.6 73.3 73.4 75.4 83.9 85.2 86.3 89.6 88.1 85.3 80.3 78.98 73.2 74.2 73.1 72.5 77.7 79.4 80.9 85.2 86.3 85.1 81.2 78.69 73 72.5 69.2 66.5 70.4 72.8 74.2 78.1 81.1 81.7 78.6 7810 69 67.4 63.3 61.2 64.1 67.8 68.5 70.9 74.2 76.2 71.2 74.711 64.5 62.2 57.8 56.9 59.3 63.7 64.1 65.3 67.5 70.9 64.6 70.512 60.1 57.7 53 53.3 56 60.2 60.4 61.2 62.5 67.2 59.5 66.313 56.3 54.3 48.6 51.2 53.2 57.7 58 57.9 59.3 64.2 55.8 63.614 53.4 51.4 45.6 49.4 51.1 55.6 56.3 55.7 56.9 62.2 53.1 61.715 51 49.9 43.4 48.4 49.8 54.8 55.6 54.5 55.5 60.5 51.2 60.616 50.1 48.4 42.1 48.1 49.3 54.3 55.6 54.1 55.1 60.1 50.8 60.417 50.8 48.9 42.2 48.7 49.9 54.3 56 55 56 60.9 53 62.218 54.2 51.7 44.5 49.1 51.3 56 57.5 56.9 59.3 64.7 58 65.719 59.1 56.9 49 51.9 54.7 58.6 60.6 62.4 67.1 70.7 63.2 68.520 62 60.6 54 56.7 61.8 64.1 67.3 70.9 75.1 73.8 66.3 70.421 64.5 63.2 57.6 60.8 68.1 71.2 74.8 76.5 78.2 76 68 71.522 65.9 65.4 60 63.7 71.7 75 78.9 79.6 80.6 77 69.7 72.623 66.9 66.9 62.2 66.5 74.5 78.1 81.3 81.8 82 78.4 71 73.824 67.7 68.4 64.1 68.7 77.4 79.9 83.2 84 82.5 79.3 72.3 74.7G-38Table 10 – Average Monthly Temperatures byHour of the Day for St. Charles Countyin Fahrenheit (MOVES Inputs for 2011 OnRoad Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 23.3 31.7 41.4 48.5 58.4 68.2 67 66 60.8 46.4 43.7 26.92 21.1 31.7 39.4 46.5 57 67.3 66.3 65.5 59.7 46.4 42.7 27.83 20 30.4 38.1 45.5 55.9 66.4 65.4 64.7 59 45.6 41.9 27.14 19.2 29.4 37.4 44.5 55 65.6 64.6 63.9 58.2 45.1 41.2 26.35 18 28 37 43.8 53.9 64.7 63.9 63.2 57.4 44.2 40.6 25.76 17.2 26.7 36 43.2 53.1 64.3 63.2 62.7 56.7 43.6 40.2 257 16.7 25.7 35.3 43.2 55 66.4 64.8 63.3 56.5 42.8 39.9 24.68 16.4 25 36 46.3 58.6 69.7 68.3 67.2 59.2 43.7 39.8 24.29 17 27 39.8 50.7 62.3 73.2 71.7 71.2 63.1 46.4 43 2510 20.5 31.2 44.3 54.3 65.5 76.4 74.4 74.8 67.2 49.8 47.6 28.211 24.3 35.4 48.4 57.7 68.2 79 76.8 77.4 70.7 52.7 51.6 31.512 27.8 39.4 51.9 60.4 70.3 81.3 78.8 79.6 73.3 55.2 54.8 34.513 30.8 42.8 54.8 62.4 72.2 83 80.4 81.5 75 57.2 57.3 36.414 33.1 45.6 56.7 63.8 73.8 84.3 81.4 82.9 76.4 58.6 58.9 38.115 34.9 47.5 58.3 64.4 75 84.4 81.9 83.6 77.3 59.6 59.9 38.916 35.8 48.5 58.7 64.5 75.1 84.8 82.1 83.6 77.5 59.8 59.6 38.717 35.3 48 58.3 63.9 74.6 84.8 81.9 83 76.9 59 58 37.218 32.6 45.5 56.6 63.1 73.8 83.8 81 81.9 75.2 56.9 54.1 33.719 29.3 41.3 52.9 61 71.9 82.1 79.6 79.1 71.4 53.6 51 31.520 27.8 39.1 49.3 57.7 68.2 79.1 76.5 74.9 67.2 51.8 49 30.321 26.3 37.4 47 55.1 64.8 75 72.6 71.7 65.5 50.4 47.9 29.522 25.7 35.7 45.2 53 62.8 72.7 70.5 70 63.9 49.3 46.5 28.823 25.1 34.2 43.6 51.3 61.1 71 69.1 68.6 62.8 48.1 45.6 28.224 24.1 32.9 42.5 49.6 59.6 69.3 68 67.2 61.7 47.3 44.6 27.8G-39Table 11 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Charles County (MOVES Inputs for 2011 OnRoad Mobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 68.6 69.6 65.2 69.8 77.2 81.7 84.3 86.6 83.9 81.3 74.7 76.52 70.4 69.8 67.3 70.1 79.1 83.4 84.8 87.5 85.3 82.6 77 77.23 70.9 70.9 69.1 71.4 80.8 84.8 85.7 88.1 85.9 84.5 78.1 77.54 71.5 71.4 70.5 72.4 82 85.7 86.9 89.6 87.1 84.4 79 78.45 72 73.1 71.3 73.5 83.1 86.9 87.1 90.3 88.1 85.7 80.2 79.36 72.2 73.9 72.7 74.6 84.3 87.5 88 90.9 89 86 81.2 807 72.5 74.4 73.5 75.2 82.6 85.4 86.9 90.3 89.3 86.6 81.8 80.38 72.8 75 73.3 72.3 75.8 79.3 81.1 85.5 87.5 85.7 82.1 80.69 72.8 73.3 69.1 65.6 68 72.9 74.1 78 81.6 82.6 79.2 79.310 69.7 67.8 62.7 60.2 61.4 67.6 68.1 70.8 74.4 77.3 72.2 75.611 65.2 62.3 57 55.5 56.6 63.8 63.5 65 67 71.9 65.2 70.712 60.7 57.6 52.3 52.2 53.2 59.8 59.9 60.6 61.6 67.9 60 66.513 56.8 53.9 47.6 49.7 50.5 57.4 57.2 57.4 58.1 65.1 56.5 64.514 53.6 50.9 44.8 47.9 48.5 55.2 55.6 54.8 55.9 62.9 54 62.615 51.6 49 42.8 47.1 46.8 54.5 55.1 53.6 54.2 61.3 52.3 61.216 50.4 47.4 42 46.9 46.5 53.8 54.9 53.1 53.7 60.7 51.9 61.417 51.2 48.1 42.1 47.4 47.2 53.6 55.3 53.7 55 61.5 53.8 6318 54.9 51.7 44.4 48.1 48.5 55.2 57.1 55.7 58.2 65.3 59 66.619 59.9 57.1 49.2 50.9 51.7 57.9 60.2 61.6 66.3 71.4 64.1 69.520 62.8 60.5 54.5 56.1 58.7 63.6 67.2 70.3 75.8 74.6 67.2 71.221 65.4 63.1 57.7 60 65.3 71.3 75.7 76.4 78.9 76.8 68.1 72.322 66.5 65.8 60.1 63.1 69.3 75.2 79.6 79.3 82 78.2 70.4 73.823 67 67.6 62.1 65.9 72.8 78 81.5 81.7 82.5 79.6 71.4 74.724 68.1 68.8 63.7 68.3 75.3 79.8 83.2 84.6 83.3 80.1 73 75.6G-40Table 12 – Average Monthly Temperaturesby Hour of the Day for St. Louis Countyin Fahrenheit (MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 24.8 33.1 42.9 50.2 61 70.2 68.9 68.1 62.6 47.7 45.9 282 22.6 33.1 41.1 48.4 59.8 69.5 68 67.6 61.7 47.6 45 28.73 21.6 32 40 47.6 58.9 68.5 67.2 66.7 61 46.8 44.2 284 20.6 31 39.2 46.5 57.9 67.6 66.3 66 60.2 46.4 43.6 27.25 19.5 29.7 38.6 45.8 57.2 66.7 65.7 65.3 59.5 45.6 43 26.66 18.6 28.4 37.8 45.3 56.4 66.5 65.1 64.8 58.8 44.9 42.5 26.17 18.1 27.4 37.3 45.3 58.1 68.6 66.6 65.4 58.6 44.3 42.3 25.78 17.8 26.8 37.8 48.2 61.2 71.7 69.8 68.9 61.1 45.2 42 25.59 18.4 28.7 41.2 52.1 64.3 75 73 72.5 64.7 47.7 45.1 26.310 21.7 32.3 45.3 55.4 66.9 78 75.5 75.9 68.5 50.8 49.7 29.311 25.5 36.2 49.2 58.5 69.3 80.4 77.8 78.5 71.6 53.8 53.3 32.512 28.6 40 52.6 61.1 71.2 82.7 79.6 80.6 74.1 56 56.3 35.513 31.6 43.2 55.1 62.9 72.6 84.4 81.3 82.4 75.6 58.1 58.5 37.414 33.9 46 57 64.2 74 85.6 82.3 83.6 76.9 59.4 60.2 39.115 35.5 47.6 58.5 64.9 75.1 85.7 82.8 84.4 77.7 60.5 61 39.916 36.4 48.4 59 65 75.2 85.8 82.9 84.3 78 60.6 60.7 39.917 35.9 48.1 58.7 64.3 74.7 85.8 82.7 83.7 77.4 59.7 59.2 38.218 33.4 45.8 57 63.4 74 84.8 81.9 82.5 75.9 57.8 55.7 34.819 30.5 42.1 53.6 61.5 72.4 83.3 80.6 79.9 72.4 54.8 52.8 32.720 28.9 40 50.3 58.5 69.2 80.6 77.7 76.1 68.9 53 51.1 31.421 27.6 38.5 48.2 56.3 66.6 77 74.3 73.4 67.2 51.7 49.9 30.422 27.2 36.9 46.3 54.5 64.8 74.8 72.2 71.7 65.8 50.7 48.6 29.923 26.6 35.7 44.8 52.9 63.5 73.1 70.9 70.4 64.7 49.5 47.9 29.324 25.6 34.4 43.7 51.3 62.2 71.5 69.7 69 63.6 48.6 46.8 28.7G-41Table 13 – Average Monthly Percent RelativeHumidity by Hour of the Day for St.Louis County (MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 69 70 65.1 70 77.4 80.7 82.9 84.9 82.8 80.5 74 75.92 70.6 70.3 67.3 70.3 79.3 81.8 83.7 86.1 84.2 82 76 76.63 71.4 71.1 68.5 71.3 81 83.5 84.9 87.3 85.1 83.9 77.4 76.94 72.3 71.6 70.1 72.6 82.2 84.9 86 88.5 86 84.2 78.3 77.85 72.5 72.9 71.2 73.7 83 86.4 86.3 89.4 87.2 85.1 79.5 78.76 73 74 72.3 74.8 84.5 86.7 86.9 90 88.1 85.8 80.7 797 72.9 74.3 73.1 75.4 82.8 84.4 86 89.7 88.4 86.1 81 79.78 73.2 75.1 73.2 72.5 76.1 78.6 79.8 85 86.7 85.1 82 79.79 73.3 73.5 69.2 66.2 68.4 72.3 73.7 77.9 80.9 82.1 79 78.410 70.2 68.5 63.1 61 62.5 67.1 67.8 70.5 73.5 76.8 71.6 74.811 65.3 62.9 57.4 56.5 57.6 63.1 63.2 64.4 66.8 71.5 64.9 70.512 61.3 58.6 52.6 52.9 54.2 59.4 59.6 59.9 61.2 67.7 59.7 66.613 57.4 54.7 48.2 50.8 51.5 56.8 56.8 56.7 58 64.5 56 64.414 54.2 51.8 45.4 48.9 49.5 54.6 55.1 54.4 55.8 62.3 53.4 62.515 52.1 50 43 47.9 47.8 53.9 54.6 52.8 54.1 60.8 52.1 61.316 51 48.5 42.1 47.5 47.3 53.4 54.7 52.6 53.4 59.9 51.6 61.117 51.8 49.1 42 48.2 48.1 53.4 55.2 53.5 54.5 60.9 53.6 63.218 55.5 52.6 44.7 49.1 49.3 54.7 56.7 55.4 57.6 64.4 58.5 66.219 60.3 57.7 49.1 51.9 52.6 57.4 59.7 61.3 65.5 70 63.6 69.120 63.3 61.4 54.2 56.9 59.5 62.5 66.1 69.3 73.5 73 66.4 70.721 65.6 63.7 57.7 60.4 65.3 69.1 73.3 75 76.9 75.7 67.8 72.122 66.4 66.5 60.2 63.3 69.2 73.1 77.6 78.1 79.8 77.1 69.8 73.323 67.2 67.7 62.3 66.3 72.5 76.3 79.9 80.5 81.2 78.5 70.5 74.124 68.2 69 64.2 68.8 75.3 78.3 82.1 83.2 82 79.3 72.1 75.3G-42Table 14 – Average Monthly Temperatures byHour of the Day for St. Louis City inFahrenheit (MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 25.9 34.7 44.1 51.8 62.1 71.4 70 69.2 64 49 48.2 29.12 23.7 34.7 42.3 50.1 61 70.5 69.4 68.8 63.2 48.9 47.4 29.53 22.8 33.7 41.4 49.4 60.1 69.7 68.5 67.9 62.3 48.1 46.7 28.94 21.9 32.6 40.7 48.4 59.2 68.8 67.7 67.2 61.7 47.7 46 28.25 21 31.5 40.2 47.8 58.5 67.9 67.1 66.5 61 47 45.5 27.46 19.9 30.3 39.5 47.3 57.7 67.7 66.6 66.1 60.4 46.3 45 277 19.3 29.3 39 47.3 59.5 69.9 68.1 66.7 60.2 45.6 44.7 26.88 18.9 28.5 39.6 50 62.7 73.3 71.2 70.3 62.7 46.6 44.4 26.69 19.6 30.5 42.8 53.8 65.7 76.6 74.4 73.9 66.1 49.2 47.7 27.410 22.9 34 46.6 56.7 68.2 79.6 77 77.3 69.9 52.3 52.2 30.511 26.5 37.5 50 59.7 70.5 81.9 79.3 79.7 72.9 55 55.7 33.612 29.5 40.8 53.2 62 72.2 84.1 80.9 81.7 75.1 57.2 58.7 36.313 32.4 43.9 55.6 63.4 73.5 85.9 82.6 83.3 76.7 59 60.8 38.114 34.5 46.5 57.3 64.7 74.8 87 83.5 84.5 77.7 60.2 62.4 39.815 36 48 58.8 65.4 75.8 87.1 84 85.2 78.5 61.2 63.2 40.816 36.7 48.6 59.3 65.4 75.8 87.1 84 85.1 78.7 61.3 62.9 40.617 36.3 48.3 58.9 64.8 75.3 87.1 83.9 84.4 78.2 60.5 61.3 38.918 33.9 46.2 57.4 63.9 74.6 86 83.1 83.3 76.7 58.5 57.8 35.719 31.2 42.7 54.3 62.2 73.1 84.5 81.8 80.7 73.3 55.5 55.1 33.620 29.8 40.7 51.1 59.4 69.8 81.7 78.9 76.9 69.9 53.9 53.3 32.421 28.5 39.3 49 57.5 67.3 78 75.5 74.3 68.3 52.6 52 31.522 28.2 38.1 47.2 55.7 65.6 75.9 73.5 72.7 67 51.7 50.9 30.723 27.4 37.2 45.9 54.3 64.4 74.1 72 71.5 65.8 50.7 50 30.324 26.7 36 44.8 52.9 63.2 72.6 70.9 70.1 65 49.9 49.2 29.7G-43Table 15 – Average Monthly Percent RelativeHumidity by Hour of the Day for St. Louis City (MOVES Inputs for 2011 On-RoadMobile Source VOC Emissions)MonthIDHourID 1 2 3 4 5 6 7 8 9 10 11 121 69.2 70.2 65.5 71 78.7 81.1 83.6 85.3 83.2 80.6 74.8 762 71 70.5 67.4 70.5 80.6 82.5 83.8 86.5 84.3 81.8 76.5 773 71.6 71 69 71.8 82.3 83.9 85 87.3 85.2 83.7 77.6 77.34 72.4 71.7 70 72.8 83.5 85 86.1 88.8 86.1 84.3 78.8 77.95 72.6 72.8 71.1 74.2 84 86.4 86.4 89.8 87 84.9 79.7 79.16 72.8 73.9 72.2 75 85.5 86.7 86.7 90.4 88.2 85.5 80.9 79.17 73.1 74.4 73 75.6 83.8 84.5 85.5 89.8 88.5 86.5 81.5 79.88 73.4 75.3 73.1 72.7 77 78.5 80 85.1 86.4 85.5 82.1 79.49 73.1 73.3 68.9 66.2 69.4 72 73.6 77.7 80.7 81.8 79.2 78.810 69.7 68.4 63 61.4 63.1 67 67.7 70.4 73.4 76.1 71.8 74.911 65.2 63.1 57.7 56.9 58.2 63.1 63 64.3 67 71 65.2 70.912 61.5 59.2 52.7 53.6 54.9 59.4 59.8 60.1 61.6 67.4 60.1 67.213 57.5 55.2 48.3 51.8 52.4 57 56.7 57 58.4 64.1 56.6 6514 54.7 52.5 45.4 49.9 50.3 54.7 55.3 54.7 56.3 62.1 53.9 62.915 52.4 50.7 42.9 48.7 48.8 54.1 54.6 53.3 54.6 60.6 52.6 61.516 51.4 49.3 41.9 48.5 48.5 53.7 54.8 53.1 54.1 60 52.2 61.717 52.3 49.7 42 49.2 49.5 53.7 55.4 53.9 55 61 54.1 63.518 55.8 53.4 44.4 50 50.6 55.3 57 55.9 58.2 64.5 59.5 66.619 60.4 58.5 49.1 52.8 54 57.8 59.9 62.1 65.9 70.6 64.1 69.220 63.1 62 54.3 57.7 61.1 63 66.3 70.1 74.2 73.7 67.2 71.121 66 64.4 58 61.3 66.8 69.9 73.4 75.9 77.5 75.8 69.1 72.222 66.5 66.6 60.9 64.2 70.9 73.7 77.9 79 80.2 77.2 70.6 7423 67.6 67.6 62.7 67.3 73.9 77.2 80.3 81.1 81.8 78.6 71.6 74.524 68.4 69.2 64.6 69.5 76.5 79 82.8 83.6 82.4 79.4 72.9 75.4

## G-44 Attachment 2 of Appendix G

Developing the I/M Input Tables for MOVES for the St. Louis Ozone nonattainment area

EPA has technical guidance on appropriate input a ssumptions and sources of data for the use of MOVES 2010 in State Implementation Plan ( http://www.epa.gov/otaq/models/moves/420b10023.pdf ). Section 3.10 of this guidance document explains the appropriate assumptions a nd methods to be used when developing the I/M input table for MOVES 2010. This guidance has b een followed in the development of I/M input
Tables 2 – 6 at the end of this document. This document outlines the approach used to develop each parameter of these I/M input tables in MO VES. The goal in developing these I/M input tables is to accurately reflect the actual I/M program being implemented in the St. Louis
nonattainment area.

Pollutant Process ID To begin development of the I/M input table, the default data for the I/M input table for St. Louis County was exported from the MOVES county data base manager. The default data included four different I/M test types. However, the actual St. Louis area only had two different test types (On-board diagnostics) OBD tests for the exhaust and evaporative systems. In the default I/M input table, these were the onl y two types of tests that were “turned on” along with the appropriate pollutant process IDs that would be impacted by each test. Therefore, the pollutant process IDs that were included in the default table for the two OB D tests were the same pollutant process IDs used in the I/M input table for the St. Louis nonattainment area. The other two tests included in the default data along with their asso ciated pollutant process IDs were still included in the I/M input table, bu t they were “turned off”.

Source Type ID The St. Louis I/M program includes passenger cars a nd also trucks with a gross vehicle weight rating of 8,500 lbs. or less. Therefore, the three source type IDs included in the I/M input table for the St. Louis nonattainment area are passenge r cars, passenger trucks, and light commercial trucks (IDs = 21, 31, and 32).

Fuel Type ID The St. Louis I/M program is applicable to bo th gasoline and diesel vehicles; however, MOVES only calculates an I/M benefit for gasoline vehicles. Therefore, the fuel type ID for gasoline was the only uel type ID used in the I/M input table for the St. Louis nonattainment area.

Inspection Frequency The St. Louis I/M program requires that emission be tested ever y two years, so the inspection frequency ID that represents biennial tests (ID = 2) was used in the I/M input table for the OBD tests applicable to the St . Louis nonattainment area.

Test Standards The St. Louis I/M program is a centralized progr am with OBD tests for exhaust and evaporative systems on the vehicles. Therefore, the test standard IDs for exhaust OBD check and the

## G-45 evaporative system OBD check (IDs = 43 and 51) we re used in the I/M input table for the St.
Louis nonattainment area.

I/M Program ID This is an arbitrary number developed by the M OVES user to define a unique test given for vehicles within a range of model years. Therefore, I/M program IDs were arbitrarily assigned to the various unique tests within the St. Louis I/M program.

Beginning and Ending Model Years The St. Louis I/M program applies to gasoline vehicles with a m odel year of 1996 or later and it also applies to diesel vehicles with a model year of 1997 or later. Since the emissions inspection is required biennially, the endi ng model year would always be tw o years less than the emissions inventory year that is being developed. Ther efore, for the tests for gasoline vehicles, the beginning model year is 1996 and the ending model ye ar is two years earlie r than the year for which MOVES is being run, and th e for diesel vehicles the be ginning model year is 1997 and the ending model year is two years earlier th an the year for which MOVES is being run.

Compliance Factor According to page 39 of the MOVES guidance doc ument the compliance factor is calculated with the following equation:

Compliance Factor = percent compliance rate x (100 – percent waiver rate) x regulatory class coverage adjustment.

Therefore, in order to calculate the compliance f actor for each source type included in the I/M program, the compliance rate, waiver rate, and regula tory class coverage adjustment needed to be determined. These three values were determined by the processes described below and then the compliance factors for each source type were calculated with the equation written above.

Compliance Rate The compliance rate was calculate d with the following equation:

Compliance Rate = Number of vehicles that we re tested over a two year period (2008 – 2009) / Population of vehicles that is theoretically subject to I/M during the same period.

In order to determine the compliance rate, as it compares to the source type population by model year, the population of vehicles th at is theoretically subject to I/M first needed to be determined.

In May 2009, the Missouri Department of Reve nue (DOR) Vehicle Registration database was queried and a VIN decoder was us ed to separate the vehicle counts into Mobile 6.2 vehicle classes by model year. In the St. Louis nonattainm ent area, the Mobile 6 .2 vehicle classes that are subject to I/M include 1996 a nd newer light duty gasoline vehi cles, light duty gasoline trucks Class 1, light duty gasoline trucks Class 2, light du ty gasoline trucks Cla ss 3, light duty gasoline trucks Class 4, as well as 1997 and newer light duty diesel vehicles, light dut y diesel trucks Class 1, light duty diesel trucks Cla ss 2, light duty diesel trucks Clas s 3, and light duty diesel trucks
Class 4. Table 1 below shows the total combined population of these 10 vehicle classes within

## G-46 the appropriate model years by county in the St. Louis nonattainment area according the May
2009 DOR data.

Table 1. Vehicles Theoretically Subject to the I/M Program in the St. Louis Nonattainment Area

1996 and later 1997 and later County Light Duty Gas (1996 and newer) Light Duty Diesel (1997 and newer) Franklin 73,300 328 Jefferson 150,998 484 St Charles 238,672 589 St Louis City 144,871 345 St Louis County 756,978 1,653
Total 1,364,819 3,399
Total Count 1,368,218



## The Air Program also queried the I/M report genera tor to determine the total number of vehicles,
which had their emissions tested at least once from January 1, 2008 through December 31, 2009. The query also included the tota l number of vehicles that receiv ed waivers during the same time period. Table 2 below, was genera ted with data from this query.

Table 2. Initially Tested Vehicles that Receive d a Waiver in the St. Louis I/M Program from January 1, 2008 through December 31, 2009

Using the data from Tables 1 and 2 above the comp liance rate is calculated for the St. Louis I/M Program with the following equation:

Compliance Rate: (1,344,747 / 1,368,218) x 100% = 98.28%

Waiver Rate

## G-47 The waiver rate is the percentage of vehicles th at fail an initial I/M test and do not pass a retest, but do receive a certificate of compliance. Th e waiver rate was determined by dividing the
number of vehicles that received waiver s from January 1, 2008 through December 31, 2009 by
the total number of vehicles that were test ed at least once during the same time period. Therefore, the waiver rate was calculated fo r the St. Louis I/M Progr am with the following equation:

Waiver Rate: (4,761 / 1,344,747) X 100% = 0.35%

Regulatory Class Coverage Adjustment The regulatory class coverage adjustment is an adjustment that accoun ts for the fraction of vehicles within a source type th at are covered by the I/M program. Since the I/M program in St. Louis exempts vehicles with a gross vehicl e weight rating above 8,500 lbs., the compliance factor needs to reflect the percen tage of vehicles in the source types subject to I/M that are exempt because of their GVWR. Table A.3 in the Appendix of the MOVES Technical Guidance Document was used to develop adjustments to the compliance factor to account for this discrepancy. The adjustments are percentages of vehicle miles traveled by the various regulatory weight classes within a source type. The corre sponding adjustment factors used for the three source categories are as follow: Passenger cars: 100% Passenger Trucks: 94% Light Commercial Trucks: 88%

Calculating the Compliance Factor Based on the calculations listed above the compliance factor for each source category impacted by the I/M program in St. Louis is listed below.

Passenger cars: 98.28% x ( 100% - 0.35%) x 100% = 97.94% Passenger Trucks: 98.28% x (100% - 0.35%) x 94% = 92.06% Light Commercial Trucks: 98.28% x (100% - 0.35%) x 88% = 86.18%

## H-1 APPENDIX H

2008/2011/2015/2017/2022 Off-Road Mobile Source Emissions

The Air Program Staff followed the 2008 and 2022 off-road modeling protocol submitted by EPA Region 7 to the Department for the development of the 2008, 2011, 2015, 2017and 2022 off-road mobile emissions with two exceptions. The Staff used 3.5% oxy gen weight instead of
0.35% and 100% ethanol blend market instead if 10%. The modeling protocol can be found in Attachment 1 of Appendix H of this document. The data generated by th e Air Program Staff for the 2008, 2011, 2015, 2017and 2022 off-road mobile sources emissions for the Missouri counties
in the St. Louis ozone nonattainment area are su mmarized in Table 1. The values in Table 1 do
not include emissions from the commercial marine vessel and railroad locomotive source categories.

Table 1
2008 Off-Road Mobile Source VOC Emissions by County in the St. Louis Ozone Nonattainment Area (E xcludes Marine and Rail Emissions) (Tons/Ozone Season Day) (Missouri Counties Only)
County Name 2008 2011 2015 2017 2022 Franklin County 3.53 3.15 2.49 2.18 1.76 Jefferson County 3.54 3.09 2.43 2.21 1.99 St. Charles County 7.32 6.15 4.65 4.27 3.83 St. Louis County 25.84 22.39 17.67 16.97 16.98 St. Louis City 3.86 3.19 2.29 2.13 2.10

Totals 44.09 37.97 29.53 27.76 26.66

## H-2 Attachment 1 of Appendix H

EPA Region 7 Off-Road Emissions Modeling Pr otocol for 2008 and 2022 for the St. Louis, Missouri Five-County Nonattainment Area

Ozone and PM2.5 Maintenance Plan Work Sha re St. Louis, Missouri Five-County Area Nonroad Modeling for Inventory Development

For this modeling exercise, the EPA Region 7 ut ilized the NONROAD2008a model to calculate an ozone and PM2.5 nonroad inventory in five coun ties in the St. Louis n onattainment area for the 1997 PM2.5 annual and 1997 Ozone NAAQS. The NONROAD2008a model provides the emissions for all nonroad source categories excep t aircraft, commercial marine vessel, and
railroad locomotive.

In running the NONROAD model, the user must specify a modeling scen ario by the inventory year, geographic area (nation, stat e, county), period (annual, seas onal, monthly, daily), and the equipment categories. For all other required variables, the NONROAD model provides default input values. For the following modeling exerci ses, fuel parameters (Reid Vapor Pressure (RVP), oxygen weight, sulfur content, ethanol vo lume and market percentage) and temperatures for each geographical area were provided by MDNR in lieu of the modeling default settings for more accurate results (see attachment).

Ozone Precursor Emissions

Ozone Methodology/Input Data: Nonroad mobile source emissions for the year s of 2008 and 2022 are calculated using the EPA approved model, NONROAD2008a, and included Franklin County, Jefferson County, St. Charles County, St. Louis County and St. Loui s City in St. Louis, Missouri. For modeling ozone precursor pollutants, temperatur es and fuel characteris tics representative of each county during an ozone summer weekday, we re entered into NONROAD2a and modeled to
calculate an ozone season w eekday emissions for nonroad sour ces. Minimum, maximum, and average temperatures for a typical summer seas on were provided by MDNR (see attachment). Modeling input parameters are as follows:

Table B-27 NONROAD Model Temperature & Fuel Char acteristic Input Values by County

County Oxygen Weight
% RVP psi Gasoline
Sulfur % Diesel
Sulfur Marine
Diesel
Sulfur

% CNG /
LPG
Sulfur

% Temperatures

Min. Max. Avg.

Franklin 0.35 7 0.0049 0.0355 0.0402 0.003 61.8 90 75.96

## H-3 Jefferson 0.35 7 0.0049 0.0355 0.0402 0.003 61 88.6 75.16

St. Charles 0.35 7 0.0049 0.0355 0.0402 0.003 62.2 89.2 76.15

St. Louis 0.35 7 0.0049 0.0355 0.0402 0.003 64.1 89.5 77.1
St. Louis City 0.35 7 0.0049 0.0355 0.0402 0.003 65.1 89.8 77.72



## Direct PM 2.5 

## / PM 2.5 

## Precursor Emissions

Methodology/Input Data: Nonroad mobile source emissions for the year s of 2008 and 2022 were calculated using the EPA approved model, NONROAD2008a, and included Franklin County, Jefferson County, St. Charles County, St. Louis County and St. L ouis City in St. Louis, Missouri. For modeling PM 2.5 

## and PM 2.5 

## precursor pollutants, temperatures and fuel characteristics representative of each county for ea ch of the four seasons (winter, spring, summer, and fall) were entered into the NONROAD2008a model as input parameters. The highest temperature and lowest temperature from each three month period (December-February, March-May, JuneAugust, and September-November) were averaged to create a seasonal average temperature. Those seasonal average temperatures, seasona l minimum and seasonal maximum temperatures were then utilized in the model, including the fuel parameters, to calculate the total emissions for each county and season. Summing the emissions of all four seasons for each county gave the total annual emissions. The temperatures and fuel characteristics represen tative of each county were provided by MDNR. Modeling i nput parameters are as follows:

Table B-28 NONROAD Model Temperature & Fuel Charac teristic Input Values by County & Season

County Season Oxygen Weight
% RVP psi Gasoline
Sulfur

% Diesel
Sulfur Marine
Diesel
Sulfur

% CNG
/ LPG
Sulfur

% Temperatures

Min. Max. Avg.
Franklin Winter 0.35 11.5 0.0043 0.0355 0.0402 0.003 19.7 47 33.4 Franklin Spring 0.35 9 0.0046 0.0355 0.0402 0.003 33.5 76.9 55.2
Franklin Summer 0.35 7 0.0049 0.0355 0.0402 0.003 61.8 90 75.9
Franklin Autumn 0.35 9 0.0046 0.0355 0.0402 0.003 34.3 80.9 57.6
Jefferson Winter 0.35 11.5 0.0043 0.0355 0.0402 0.003 18.6 45.6 32.1 Jefferson Spring 0.35 9 0.0046 0.0355 0.0402 0.003 32.4 75.8 54.1
Jefferson Summer 0.35 7 0.0049 0.0355 0.0402 0.003 61 88.6 74.8
Jefferson Autumn 0.35 9 0.0046 0.0355 0.0402 0.003 33.6 79.8 56.7
St. Charles Winter 0.35 11.5 0.0043 0.0355 0.0402 0.003 18.7 43.9 31.3 St. Charles Spring 0.35 9 0.0046 0.0355 0.0402 0.003 32.3 75.8 54.1
St. Charles Summer 0.35 7 0.0049 0.0355 0.0402 0.003 62.2 89.2 75.7
St. Charles Autumn 0.35 9 0.0046 0.0355 0.0402 0.003 34.8 80.3 57.6

St. Louis Winter 0.35 11.5 0.0043 0.0355 0.0402 0.003 19.8 44.2 32 St. Louis Spring 0.35 9 0.0046 0.0355 0.0402 0.003 34.5 76.1 55.3
St. Louis Summer 0.35 7 0.0049 0.0355 0.0402 0.003 64.1 89.5 76.8
St. Louis Autumn 0.35 9 0.0046 0.0355 0.0402 0.003 35.5 80.2 57.9
St. Louis City Winter 0.35 11.5 0.0043 0.0355 0.0402 0.003 20.7 45.5 32.6

## H-4 St. Louis City Spring 0.35 9 0.0046 0.0355 0.0402 0.003 35.7 76.4 56
St. Louis City Summer 0.35 7 0.0049 0.0355 0.0402 0.003 65.1 89.8 77.5
St. Louis City Autumn 0.35 9 0.0046 0.0355 0.0402 0.003 36.6 80.4 58.5



## QA/QC: Quality control and quality assurance were conducted throughout this nonroad modeling process.
Data collected from various data sources were ve rified and correctly ente red or transcribed into the model. In some instances, input values, i.e., temperatures and fuel values were double and/or triple checked for accuracy to insure they corresponded to the data supplied by MDNR. In addition, a spot-checking of the modeling results , including rerunning the model for those results in question, was perfor med to insure reliability

## Jay Nixon, Governor Sara Parker Pauley, Director


# Air Pollution Control Program

Rulemakings on Public
Notice

The Missouri Department of Natural Resources filed the following proposed rulemakings with the secretary of state's office and comme nts are being accepted as noted at the end of the proposed rulemaking under the Notice of Public Hearing and Notice to Submit Comments heading. To submit comments electronica lly, use the links below the rule or to submit written comments see the address below.

10 CSR 10-5.220 Control of Petrol eum Liquid Storage, Loading and Transfer

This proposed amendment will remove the requirements for Stage II vapor recovery controls at gasoline dispensing faci lities (GDFs) in the St. Louis area. Stage II systems control emissions of volatile organic compound s during vehicle refueling and have been an ozone-reduction measure in the St . Louis area since the late 1980s. In May 2012, the U.S. Environmental Protection Agency (EPA) determ ined that Onboard Refueling Vapor Recovery (ORVR) technology is in widesp read use throughout the motor vehicle fleet for purposes of controlling motor vehicle refueling emissions. ORVR is an improved method of controlling the vapor displaced during refueling that is built into newer motor vehicles. ORVR makes Stage II controls obsolete, an d EPA’s widespread use determin ation allows th e removal of Stage II controls if Clean Air Act anti-backsliding requirements are met to ensure air quality is not adversely impacted. EPA has already given verbal concurrence on our technical analysis showing removal of St age II controls as proposed in this rulemaking will not adversely affect St. Louis air quality.

The rulemaking will also address the following items:

Certification and testing proced ures for the re maining Stage I systems will use the California Air Resources Boar d (CARB) vapor recovery prog ram instead of the Missouri Performance and Test Procedures (MOPETP). Stage I systems capture displaced vapors when fuel storage tanks at GDFs are loaded from delivery vessels. •

The prohibition of abovegro und storage tanks (ASTs) at GDFs will be codified. The rule never allowed ASTs becaus e MOPETP never certified ASTs. Elimination of MOPETP requires adding language to the rule to clarify that ASTs will continue to be prohibited. •

Permitting provisions will be revised to address the decommissioning of Stage II systems and clarify the permitting requ irements and fees for Stage I systems. The permitting fees will remain $100 per permit but the frequency with which permits are issued will change. •

Proposed Rulemaking – Published in April 1, 2014 Missouri Register Pa g e 1 of 2 Rulemakin g s on Public Notice - DN R

4/7/2014 htt p ://www.dnr.mo. g ov/env/a p c p /rulemakin g .htm

## Technical Support Document

Additional Information on this rulemaking.

Submit comments now Submit written comments

Comments on this rulemaking will be accept ed through close of business June 5, 2014.

10 CSR 10-6.165 (amendment) Restri ction of Emission of Odors

This proposed amendment will remove the de finitions of “Modification” and “Class IA concentrated animal feeding op eration” found in 10 CSR 10-6.1 65, Restriction of Emission of Odors, since these two definitions can be found in 10 CSR 10- 6.020, Definitions and Common Reference Tables. This rulemaking is administrative in nature and does not add new requirements.

Proposed Rulemaking – Published in March 17, 2014 Missouri Register

Additional Information on this rulemaking.

Submit comments now Submit written comments

Comments on this rulemaking will be acce pted through close of business May 1, 2014.

Submit written comments abou t any rule development to: Chief, Air Quality Planning Section Missouri Department of Natural Resources Air Pollution Control Program P.O. Box 176 Jefferson City, MO 65102-0176

Back to top Pa g e 2 of 2 Rulemakin g s on Public Notice - DN R

4/7/2014 htt p ://www.dnr.mo. g ov/env/a p c p /rulemakin g .htm1 

## Bechtel, Cheri

From: Missouri DNR <MODNR@public.govdelivery.com>

Sent: Friday, April 25, 2014 2:54 PM

To: Bungart, Renee; Archer, Larry; Lovejoy, Victoria ; Moore, Kyra; Vit, Wendy; Bechtel, Cheri; Crawford, Betsy; Terlizzi, Gena Subject: Courtesy Copy: Missouri DNR Air Public No tices Update - Missouri Air Conservation Commission Public Hearing, May 29, 2014



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MISSOURI AIR CONSER VATION COMMISSION
WILL HOLD PUBLIC HEARING

JEFFERSON CITY, MO -- The Missouri Air Conser vation Commission will hol d a public hearing on Thursday, May 29, 2014 beginning at 9 a.m. at the St . Louis Regional Office, 7545 S. Lindbergh, Suite 220, DESE Conference Room, St. Louis, Missouri. The co mmission will hear testimony related to the following

p roposed action(s):

* 10 CSR 10-5.220 (amendment) Control of Petroleum Liquid Storage, Loading and Transfer

This proposed amendment will remove the requireme nts for Stage II vapor recovery controls at gasoline dispensing facilities (GDFs) in the St. L ouis area. Stage II systems control emissions of volatile organic compounds during ve hicle refueling and have been an ozone-reduction measure in the St. Louis area since the late 1980s. In May 2012, th e U.S. Environmental Protection Agency (EPA) determined that Onboard Refueling Vapor Recove ry (ORVR) technology is in widespread use throughout the motor vehicle fleet for purposes of controlling motor vehicle refueling emissions. ORVR is an improved method of c ontrolling the vapor displaced duri ng refueling that is built into newer motor vehicles. ORVR makes Stage II c ontrols obsolete, and EPA’s widespread use determination allows the removal of Stage II contro ls if Clean Air Act anti-backsliding requirements are met to ensure air quality is not adversely impacted. EPA has al ready given verbal concurrence on our technical analysis showing remo val of Stage II controls as propos ed in this rulemaking will not adversely affect St. Louis air quality. The rule making will also address the following items: - Certification and testing procedures for the remaining Stage I systems will use the California Air Resources Board (CARB) vapor recovery program instead of the Missouri Performance and Test Procedures (MOPETP). Stage I systems capture displaced vapors when fuel storage2 

## tanks at GDFs are loaded from delivery vessels. - The prohibition of aboveground storage tanks (ASTs) at GDFs will be codified. The rule never
allowed ASTs because MOPETP never certif ied ASTs. Elimination of MOPETP requires adding language to the rule to clarify that ASTs will continue to be prohibited. - Permitting provisions will be revise d to address the decommissioning of Stage II systems and clarify the permitting requirements and fees for Stage I systems. The permitting fees will remain $100 per permit but the frequency with which permits are issued will change.

* Missouri State Implementation Plan Revision – Regional Haze Plan 5-Year Progress Report

The federal Clean Air Act establishe s requirements for the protection of visibility in Class I areas, consisting of national parks and wilderness areas. St ates are required to submit state implementation plans (SIPs) that demonstrate reasonable progress toward meeting the national goal of a return to natural visibility conditions in Cl ass I areas by 2064. There are two Cl ass I areas in Missouri: Hercules Glades Wilderness Area and Mingo National Wildlif e Refuge. Missouri’s regional haze SIP, which was submitted to the U.S. Environmental Protection Agency in August 2009, established visibility goals for the year 2018 for each of the state’s Cla ss I areas in order to make reasonable progress toward the 2064 goal. The purpose of this report is to assess progress made toward the 2018 visibility goals in Hercules Glades and Mingo in the fi ve years since Missouri’s regional haze SIP was submitted to EPA. This 5-year progress report dem onstrates that both of Missouri’s Class I areas are expected to meet their 2018 visibility goals base d on control strategies currently in place, which largely consist of sulfur dioxide and nitrogen oxides emission re duction measures for utilities, industrial boilers, a nd other sources.

* Missouri State Implementation Plan Revision – Marginal Area Plan for th e Missouri Portion of the St.
Louis Nonattainment Area for the 2008 8-Hour Ground Level Ozone National Ambient Air Quality
Standard

The purpose of this State Implementation Plan (SIP) revision is to address th e emissions inventory and other marginal ozone nonattainme nt area requirements pursuant to Clean Air Act Section 182(a) for the Missouri portion of the St. Louis nonattain ment area under the 2008 8-hour ozone national ambient air quality standard (NAAQS). The Missour i portion of the St. Louis nonattainment area includes the City of St. Louis a nd the Counties of St. Louis, St. Charles, Franklin, and Jefferson, which were designated as a marginal nonattain ment area under the 2008 8-hour ozone NAAQS on May 21, 2012.

* 10 CSR 10-6.040 (amendment) Reference Methods

This proposed amendment will update the incorporation by reference date to include the latest Federal Register notices for ambient air monitoring met hods. Two of these notices promulgated existing methods as new equivalency methods for measuring lead, nitrogen dioxide, particulate matter less than 2.5 microns, particulate matter less than 10 mi crons, and particulate matter between 10 and 2.5 microns in diameter. In addition, EPA finalized a new Federal Reference Method for measuring lead in total suspended particulate matte r and, at the same time, designated it as a new Federal Equivalency
Method.

If the Commission adopts the action(s), it will be the De partment’s intention to submit the action(s) to the U.S. Environmental Protection Agency to be incl uded in Missouri’s State Implementation Plan unless
otherwise noted above.

Documents for the above item(s) will be available for review at the Missour i Department of Natural3 

## Resources, Air Pollution Control Progr am, 1659 Elm Street, Jefferson City, (573) 751-4817 and in the Public Notices section of the program web site http://dnr.mo.gov/env/apcp/publicnotices.htm. This information will be available at least 30 days prior to the public hearing date.

The Department will accept written or email comments for the record until 5 p.m. on June 5, 2014. Please send written comments to Chief, Air Quality Planning Section, Air Pollution Control Program, P.O. Box 176, Jefferson City, MO 65102-0176. Email comments may be submitted via the program web site noted above. All written and email comments and public hear ing testimony will be equally considered.

Citizens wishing to speak at the public hearing should notify the secretary to th e Missouri Air Conservation Commission, Missouri Department of Natural Resour ces, Air Pollution Control Program, P.O. Box 176, Jefferson City, Missouri 65102-0176, or telephone ( 573) 526-3420. The Department requests persons intending to give verbal presenta tions also provide a wr itten copy of their testimony to the commission secretary at the time of the public hearing.

Persons with disabilities requiring special services or accommodations to attend the meeting can make arrangements by calling the Program di rectly at (573) 751-4817, the Divisi on of Environmental Quality's toll free number at (800) 361-4827, or by writing two weeks in advance of the meeting to: Missouri Department of Natural Resources, Air Conservation Commissi on Secretary, P.O. Box 176, Jefferson City, MO 65102. Hearing impaired persons may contact the program through Relay Missouri, (800) 735-2966.

You are subscribed to the Air Publ ic Notices topic for Missouri DNR. Th is information has recently been updated, and is now available at the link below. Tha nk you for your interest in the Air Public Notices.

Celebrating 40 years of taking ca re of Missouri's natural reso urces. To learn more visit dnr.mo.gov

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### PUBLIC HEARING 5/29/2014

www.midwestlitigation.com Phone: 1.800.280.3376 Fax: 314.644.1334 MIDWEST LITIGATION SERVICES Page 1



### 1 MISSOURI AIR CONSERVATION COMMISSION MEETING

2 St. Louis Regional Office

3

4

5

6

7

8

9

10

11

12 PUBLIC HEARING

13 TAKEN ON BEHALF OF

14 THE MISSOURI DEPARTMENT OF NATURAL RESOURCES

15 MAY 29, 2014

16

17

18

19

20

21

22 (Starting time of the hearing: 9:01 a.m.)

23

24

25

### PUBLIC HEARING 5/29/2014

www.midwestlitigation.com Phone: 1.800.280.3376 Fax: 314.644.1334 MIDWEST LITIGATION SERVICES Page 5



### 1 IT IS HEREBY STIPULATED AND AGREED that

2 this hearing may be taken in shorthand b y

3 Rebecca Brewer, RPR, CRR, CSR, Certified

4 Court Reporter, and Notary Public, and

5 afterwards transcribed into typewriting;

6 * * * * *

7 MR. PENDERGRASS: The hearing will come t o

8 order. Let the record show the following

9 commissioners are present: Jack Baker, Mark

10 Garnett, Gary Pendergrass, and David Zimmermann.

11 The Air Conservation Commission of the State of

12 Missouri has called this public hearing pursuant to

13 Section 643.070, Revised Statutes of Missouri, E PA

14 Promulgated Rule 40 CFR 51.102 for the purpose o f

15 hearing testimony related to: 10 CSR 10-5.220,

16 amendment, Control of Petroleum Liquid Storage,

17 Loading and Transfer; Missouri State Implementat ion

18 Plan Revision, Regional Haze Plan, 5-year Progre ss

19 Report; Missouri State Implementation Plan

20 Revision, Marginal Area Plan for the Missouri

21 Portion of the St. Louis Non-Attainment area for

22 the 2008 8-hour Ground Level Ozone National Ambi ent

23 Air Quality Standard; and 10 CSR 10-6.040,

24 amendment, Reference Methods.

25 The hearing record will close at 5

### PUBLIC HEARING 5/29/2014

www.midwestlitigation.com Phone: 1.800.280.3376 Fax: 314.644.1334 MIDWEST LITIGATION SERVICES Page 8



### 1 Of lawful age, produced and sworn, depos es

2 and says:

3 MR. PAYNE: Mr. Chairman, members of the

4 Commission, my name is Stan Payne. I'm employed

5 with the Missouri Department of Natural Resources

6 Air Pollution Control Program. I work at 1659 Ea st

7 Elm Street in Jefferson City, Missouri. I'm here

8 to present testimony for the proposed amendment t o

9 10 CSR 10-5.220, Control of Petroleum Liquid

10 Storage, Loading and Transfer. The rule

11 information starts on Page 63 of the briefing

12 document.

13 The primary purpose of the propose d

14 amendment is the removal of requirements for Stag e

15 II vapor recovery controls at gasoline dispensing

16 facilities, or GDFs, in the St. Louis ozone

17 non-attainment area. Stage II systems control

18 emissions of volatile organic compounds, or VOCs,

19 during vehicle refueling and have been an ozone

20 reduction measure in the St. Louis area since the

21 late 1980s. In May, 2012, the U.S. Environmental

22 Protection Agency determined that on board refuel ing

23 vapor recovery, known as ORVR, is in widespread u se

24 throughout the motor vehicle fleet for controllin g

25 refueling emissions. ORVR is an improved method of

### Title 10—DEPARTMENT OF NATURAL RESOURCES Division 10—Air Conservation Commission Chapter 5—Air Quality Standards and Air Pollution Control Rules Specific to the St. Louis Metropolitan Area

PROPOSED AMENDMENT

10 CSR 10-5.220 Control of Petroleum Liquid Storage, Loading and Transfer . The commission proposes to amend subsections (1)(C), (2)(A), (3)(B)–(3)(E), (4)(B), and (5)(A)–(5)(C); delete subsection (3)(K) and original subsections (2)(B)–(2)(I), (3)(F), (4)(C), (4)(E), and (5)(D)–(5)(F); renumber and amend original subsections (3)(G)–(3)(J), (4)(F), and (5)(G); and renumber original subsections (2)(J) and (4)(D). If the commission adopts this rule action, it will be the department’s intention to submit this rule amendment to the U.S. Environmental Protection Agency to replace the current rule that is in the Missouri State Implementation Plan. The evidence supporting the need for this proposed rulemaking is available for viewing at the Missouri Department of Natural Resources’ Air Pollution Control Program at the address listed in the Notice of Public Hearing at the end of this rule. More information concerning this rulemaking can be found at the Missouri Department of Natural Resources’ Environmental Regulatory Agenda website, www.dnr.mo.gov/regs/index.html.

PURPOSE: This rule restricts volatile organic compound emissions from the handling of petroleum liquids in five (5) specific areas: petroleum storage tanks with a capacity greater than forty thousand (40,000) gallons, the loading of gasoline into delivery vessels, the transfer of gasoline from delivery vessels into storage containers,gasoline delivery vessels, and the fueling of motor vehicles from storage containers. This rule is required to achieve the federally mandated reduction of hydrocarbon emissions in the St. Louis metropolitan area that contribute to the formation of ozone. This amendment will remove requirements for S tage II v apor recovery systems for gasoline dispensing facilities (GDFs) in the St. Louis area, use California Air Resources Board for certification of vapor recovery equipment in place of Missouri Performance Evaluation Test Procedure, codify the prohibition of above ground storage tanks that store gasoline at GDFs, and update the permitting provisions for vapor recovery systems. The evidence supporting the need for this proposed rulemaking, per 536.016, RSMo, is Federal Register notice 77 FR 28772, dated May 16, 2012, which is the U.S. Environmental Protection Agency’s widespread use rule.

(1) Applicability.

(C) Exemptions to [t] T his [r] R

ule [include:] and/or Specific Areas of This Rule. 1. [Petroleum storage tanks that meet the following requirements shall be exempt from subsection (3)(A) of this rule:] Petroleum sto rage tanks. Subsection (3)(A) of this rule shall not apply to petroleum sto rage tanks that— A. [Are used to s] S tore processed and/or treated petroleum or condensate [when it is stored, processed and/or treated] at a drilling and production installation prior to custody transfer; B. Contain a petroleum liquid with a true vapor pressure less than 27.6 kilopascals (kPa) (4.0 psia) at ninety degrees Fahrenheit (90 °F); C. Are [of] welded construction, and equipped with a metallic-type shoe primary seal and have a shoe-mounted secondary seal or closure devices of demonstrated equivalence approved by the staff director; and
D. [Are used to s] S tore waxy, heavy pour crude oil. 2. Gasoline loading. [Subsection (3)(B) of this rule shall not apply to a loading installation whose average monthly throughput of gasoline is less than or equal to one hundred twenty thousand (120,000) gallons when averaged over the most recent calendar year, provided that the installationloads gasoline by submerged loading and meets the following requirements:] A. [To maintain the exemption, these installations shall submit a report on a form supplied by the department no later than February 1 of each year to the staff director stating gasoline throughput for each month of the previouscalendar year. After the effective date of this rule, any revision to the department supplied forms will be presented to the regulated community for a forty-five (45)-day comment period;] Subsection (3)(B) of this rule shall not apply to a gasoline loading installation whose ave rage monthly throughput of gasoline is less than or equal to one hundred twenty thousand (120,000) gallons when averaged over the most recent calendar year, provided the gasoline loading installation loads gasoline by submerged filling and— (I) Owners or operators of gasoline loading installations submit a report to the staff director on a form supplied by the



### 769 

# Proposed Rules

Proposed Amendment Text Reminder:
Boldface text indicates new matter

. [Bracketed text indicates matter being deleted.]



# U nder this heading will appear the text of proposed rules and changes. The notice of proposed rulemaking is required to contain an explanation of any new rule or any change in an existing rule and the reasons therefor. This is set out in the Purpose section with each rule. Also required is acitation to the legal authority to make rules. This appears following the text of the rule, after the word “Authority.” 

# E ntirely new rules are printed without any special symbology under the heading of proposed rule. If an existing rule is to be amended or rescinded, it will have a heading of proposed amendment or proposed rescission. Rules which are proposed to be amended will have new matter printed in boldface type and matter to be deleted placed in brackets. 

# A n important function of the Missouri Register is to solicit and encourage public participation in the rulemaking process. The law provides that for every proposed rule, amendment, or rescission there must be a notice that anyone may comment on the proposed action. This comment may take different forms. 

# I f an agency is required by statute to hold a public hearing

before making any new rules, then a Notice of Public Hearing will appear following the text of the rule. Hearing dates must be at least thirty (30) days after publication of the
notice in the Missouri Register. If no hearing is planned or required, the agency must give a Notice to Submit Comments. This allows anyone to file statements in support of or in opposition to the proposed action with the agencywithin a specified time, no less than thirty (30) days after publication of the notice in the Missouri Register

. 

# A n agency may hold a public hearing on a rule even though not required by law to hold one. If an agency allows comments to be received following the hearing date, the close of comments date will be used as the beginning day in the ninety- (90-) day-count necessary for the filing of the order of rulemaking. 

# I f an agency decides to hold a public hearing after planning

not to, it must withdraw the earlier notice and file a new notice of proposed rulemaking and schedule a hearing for a date not less than thirty (30) days from the date of publication of the new notice. M ISSOURI R EGISTER April 1, 2014 Vol. 39, No. 7department stating the gasoline throughput for each month of the previous calendar year. The report shall be submitted no later than February 1 of each year; (II) Delivery vessels purchased after December 31, 1995, are Stage I equipped;(III) Owners or operators of gasoline loading installations maintain records of gasoline throughput and gasoline delivery; and (IV) Delivery vessels operated by an exempt installationdo not deliver to Stage I controlled tanks unless the delivery vessel is equipped with and employs Stage I controls.
B. [Delivery vessels purchased after December 31, 1995, shall be Stage I equipped;] A gasoline loading installation that fails to meet the requirements of the exemption in subparagraph (1)(C)2.A. of this rule for one (1) calendar year shall not qualify for the exemption again.[C. A loading installation that fails to meet the requirements of the exemption for one (1) calendar year shall not qualify for the exemption again; D. To maintain the exemption, owners or ope rators shall maintain records of gasoline throughput and gasoline delivery; and E. Delivery vessels operated by an exempt installationshall not deliver to Stage I controlled tanks unless the delivery vessel is equipped with and employs Stage I controls.]
3. This rule does not apply to [S] s tationary gasoline tanks with a capacity of less than or equal to five hundred (500) gallons.
4. [Fueling of motor vehicles. Installations with one thousand (1,000) gallon or smaller tank(s) and monthly throughput of less than or equal to ten thousand (10,000) gallons of gasoline through the tanks are exempt from subsection (3)(E) of this rule] Subsection (3)(E) of this rule does not apply to anygasoline dispensing facility (GDF) with one thousand (1,000) gallon or smaller tank(s) and monthly throughput of less than or equal to ten thousand (10,000) gallons of gasoline through the tanks

. 5. [Gasoline transfer provisions per paragraph (3)(C)2. of this rule shall not apply to transfers made to storage tanks equipped with floating roofs or their equivalent] Paragraph (3)(C)2. of this rule does not apply to gasoline transfers made to storage tanks equipped with floating roofs or their equivalent

. 6. [Gasoline transfer provisions per paragraphs (3)(C)1.–4. of this rule shall not apply to stationary storage tanks having a capacity less than or equal to two thousand(2,000) gallons used exclusively for the fueling of implements of agriculture] Subsection (3)(C) of this rule does not apply to any sto rage tank having a capacity less than or equal to two thousand (2,000) gallons used exclusively for the fueling of agricultural equipment

. 7. [Fueling of motor vehicles pursuant to subsection (3)(E) of this rule shall not apply to any stationary tank usedprimarily for the fueling of agricultural implements or implements of husbandry. For purposes of subsection (3)(E), agricultural implements and implements of husbandry shall refer to vehicles exempted from licensing requirements by the Missouri Department of Revenue] Subsection (3)(E) of this rule does not apply to any stationary sto rage tank used primarily for the fueling of agricultural equipment

. [8. Initial fueling of motor vehicles. Subsection (3)(E) of this rule shall not apply to any refueling system used for the initial fueling of motor vehicles as defined in subsection (2)(E) of this rule. 9. Ancillary refueling of motor vehicles. Subsection (3)(E) of this rule shall not apply to any ancillary refueling system used for the refueling of motor vehicles as defined in subsection (2)(A) of this rule.]

(2) Definitions. (A) [Ancillary refueling system—Any gasoline dispensinginstallation, including related equipment, that shares a common storage tank with an initial fueling system as defined in subsection (2)(E) of this rule. The purpose of an ancillaryrefueling system is to refuel in-use motor vehicles at automobile assembly plants] Agricultural equipment—Any equipment used exclusively for agricultural purposes on land owned or leased for the production of farm products

.

[(B) CARB—California Air Resources Board, 2020 L Street, PO Box 2815, Sacramento, CA 95812.

(C) Department—Missouri Department of Natural Resources, PO Box 176, Jefferson City, MO 65102.

(D) Director—The director of the Missouri Department of Natural Resources, or a designated representative to carry out the duties as described in 643.060 of the Missouri Air Conservation Law.

(E) Initial fueling of motor vehicles—The operation, including related equipment, of dispensing gasoline fuel into a newly assembled motor vehicle at an automobile assemblyplant while the vehicle is still being assembled on the assembly line. The newly assembled motor vehicles being fueled on the assembly line have fuel tanks that have never before contained gasoline fuel.

(F) MO/PETP—The Missouri Performance Evaluation TestProcedures, a set of test procedures for evaluating performance of Stage I/II vapor control equipment and systems to be installed or that have been installed in Missouri. Contact the department for a copy of the current MO/PETP.

(G) Staff director—Director of the Air Pollution ControlProgram of the Department of Natural Resources, or a designated represe ntative.

(H) System—Manufacturer’s application of one of the specific designs for Stage II vapor recovery.

(I) Vapor recovery system modification—Any repair, replacement, alteration or upgrading of Stage I or Stage II vapor recovery equipment or gasoline dispensing equipmentequipped with Stage II vapor recovery beyond normal maintenance of the system as permitted by the staff director. Replacement of equipment with like equipment shall not be considered a vapor recovery system modification.]

[(J)] (B) Definitions of certain terms specified in this rule, other than those defined in this rule section, may be found in 10 CSR 10-
6.020.

(3) General Provisions.

(B) Gasoline Loading.

1. No owner or operator of a gasoline loading installation or delivery vessel shall cause or permit the loading of gasoline into any delivery vessel from a gasoline loading installation unless the gasoline loading installation is equipped with a vapor recovery system or equivalent. This system or system equivalent shall be approved by thestaff director and the delivery vessel shall be in compliance with subsection (3)(D) of this rule.
2. Gasoline [L] l oading shall be accomplished in a manner thatthe displaced vapors and air will be vented only to the vapor recovery system. Measures shall be taken to prevent liquid drainage from the loading device when it is not in use or to accomplish completedrainage before the loading device is disconnected. The vapor disposal portion of the vapor recovery system shall consist of one (1) of the following:A. An absorber system, condensation system, membrane system , or equivalent vapor disposal system that processes the vaporsand gases from the equipment being controlled and limits the discharge of VOC into the atmosphere to ten (10) milligrams of VOC vapor per liter of gasoline loaded; B. A vapor handling system that directs the vapor to a fuel gas system; or C. Other equipment of an efficiency equal to or greater than 

## Page 770 Proposed Rules April 1, 2014 Vol. 39, No. 7subparagraph (3)(B)2.A. or B. of this rule if approved by the staff director. 3. Reporting and record keeping shall be per subsection (4)(B) of this rule.

(C) Gasoline Transfer at GDFs

.

1. No owner or operator of a gasoline sto rage tank or delivery vessel shall cause or permit the transfer of gasoline from a delivery vessel into a gasoline sto rage tank with a capacity greater than five hundred (500) gallons and less than or equal to one thousand (1,000) gallons unless— A. The gasoline storage tank is equipped with a submergedfill pipe extending unrestricted to within six inches (6") of the bottom of the tank, and not touching the bottom of the tank, or the storage tank is equipped with a system that allows a bottom fill condition;
B. All gasoline storage tank caps and fittings are vapor-tight when gasoline transfer is not taking place; and
C. Each gasoline storage tank is vented via a conduit that is—

(I) At least two inches (2") inside diameter; and (II) At least twelve feet (12') in height above grade; and (III) [Equipped with a pressure/vacuum valve that is CARB certified and MO/PETP approved at three inches water column pressure/eight inches water column vacuum (3”wcp/8”wcv) except when the owner or operator provides
docume ntation that the system is CARB certified or MO/PETP approved for a different valve and will not function properlywith a 3”wcp/8”wcv valve. Initial fueling of motor vehicle systems and ancillary refueling systems previous MO/PETP approval applies for pressure/vacuum values] Equipped with a pressure/vacuum valve that is certified by the California AirResources Board (CARB) at three inches water column pressure/eight inches water column vacuum (3"wcp/8"wcv) except when the owner or operator provides documentation that the vapor recovery system is CARB-certified for a different valve and will not function properly with a 3"wcp/8"wcv valve

. 2. [Stationary storage tanks having a volume greater than one thousand (1,000) and less than forty thousand (40,000) gallons shall also be equipped with a Stage I vaporrecovery system that has a collection efficiency of ninetyeight percent (98%) that is based on MO/PETP, and the delivery vessels to these tanks shall be in compliance with subsection (3)(D) of this rule.] No owner or operator of a gasoline sto rage tank or delivery vessel shall cause or permit the transfer of gasoline from a delivery vessel into a gasoline sto rage tank with a capacity greater than one thousand (1,000) and less than forty thousand (40,000) gallons unless—
A. [The vapor recovery system shall collect no less than ninety-eight percent (98%) by volume of the vapors displaced from the stationary storage tank during gasoline transfer and shall return the vapors via a vapor-tight return line to the delivery vessel. All fill ports and vapor ports shall have Mo/PETP poppeted fittings.] The gasoline sto rage tank is equipped with a Stage I vapor recovery system that is certified by a CARB Executive Order as having a collection efficiency of at least ninety-eight percent (98%);
B. [A delivery vessel shall be reloaded only at installations complying with the provisions of subsection (3)(B) of this rule.] The delivery vessel to these tanks is in compliance with subsection (3)(D) of this rule;
C. [This subsection shall not be construed to prohibitsafety valves or other devices required by governmental regulations.] All vapor ports are poppeted fittings;D. The delivery vessel is reloaded at installations complying with the provisions of subsection (3)(B) of this rule; E. The vapor recovery system employs one (1) vapor line per product line during the transfer. The staff director may approve other delivery systems submitted to the department with test data demonstrating compliance with subparagraph (3)(C)2.A. of this rule; F. All vapor hoses are at least three inches (3") inside diameter; and G. All product hoses are less than or equal to four inches (4") inside diameter.
3. [No owner or operator of a gasoline delivery vessel shall cause or permit the transfer of gasoline from a delivery vessel into a storage tank with a capacity greater than one thousand (1,000) gallons and less than forty thousand (40,000) gallons unless—] Owners or operators of GDFs with monthly throughput greater than one hundred thousand (100,000) gallons may use a vapor recovery system that deviates from the requirements of subparagraph (3)(C)2.A. of this rule only if the vapor recovery system is approved by the director and has a collection efficiency of at least ninety-eight percent (98%). [A. The owner or operator employs one (1) vapor line per product line during the transfer. The staff director mayapprove other delivery systems upon submittal to the department of test data demonstrating compliance with subparagraph (3)(C)2.A. of this rule; B. The vapor hose(s) employed is no less than three inches (3”) inside diameter; and C. The product hose(s) employed is no more than four inches (4”) inside diameter. 4. Reporting and record keeping shall be per subsection (4)(C) of this rule.] 4. Aboveground gasoline sto rage tanks at GDFs shall not have a capacity greater than one thousand (1,000) gallons. 5. This subsection does not prohibit safety valves or other devices required by government regulations.

(D) Gasoline Delivery Vessels.

1. No owner or operator of a gasoline delivery vessel shall operate or use a gasoline delivery vessel which is loaded or unloaded at an installation subject to subsection (3)(B) or (3)(C) of this rule
unless—A. The delivery vessel is tested annually to demonstrate compliance with the test method specified in 40 CFR [part 63, subpart R, section] 63.425(e); B. The owner or operator obtains the completed test results signed by a representative of the testing installation upon successful completion of the leak test. [Blank test certification application forms for the test results will be provided to the testing installations by the department. After the effective date of this rule, any revision to the department supplied forms will be presented to the regulated community for a forty-five (45)-day comment period. The owner or operator shall send a copy of the signed successful test results to the staff director. The staff director, upon receipt of acceptable testresults, shall issue an official sticker to the owner or operator; C. The Missouri sticker is placed on the upper left portion of the back end of the vessel;] [D.] C. [The delivery vessel is repaired by the owner or operator and retested within fifteen (15) business days oftesting if it does not meet the leak test criteria of subparagraph (3)(D)1.A. of this rule] A copy of the vessel’s current test results are kept with the delivery vessel at all times and made immediately available to the staff director upon request ; and [E.] D. [A copy of the vessel’s current Tank Truck Tightness Test results are kept with the delivery vessel at all times and made immediately available to the staff director upon request] The delivery vessel is repaired by the owner or operator and retested within fifteen (15) business days of testing if it does not meet the leak test criteria of subparagraph (3)(D)1.A. of this rule

. 2. An owner or operator of a gasoline delivery vessel who can demonstrate to the satisfaction of the staff director that the vessel has passed a current annual leak test in another state shall be deemed to 

## Page 771 April 1, 2014 Vol. 39, No. 7 

### Missouri Registerhave satisfied the requirements of subparagraph (3)(D)1.A. of this rule, if the other state’s leak test program requires the same gauge pressure and test procedures as specified in subparagraph (3)(D)1.A. of this rule. [The owner or operator shall apply for a Missouristicker and display the Missouri sticker on the upper left portion of the back end of the delivery vessel.] 3. Reporting and record keeping shall be [per] performed as specified in subsection [(4)(D)] (4)(C) of this rule.
4. This subsection [shall not be construed to] does not prohibit safety valves or other devices required by government [al safety] regulations.

(E) Fueling of Motor Vehicles at GDFs

.

[1. Except as provided in subsections (3)(A)–(C) of this rule, no owner or operator shall install, permit the use of or maintain any stationary gasoline tank with a capacity ofmore than one thousand (1,000) gallons or operate an installation with a monthly throughput of greater than ten thousand (10,000) gallons of gasoline through tanks in the one thousand (1,000) gallon or smaller class unless the storagetank(s) is equipped with a vapor recovery system. The system shall be approved by the staff director based on the MO/PETP and shall be capable of—A. Collecting the hydrocarbon vapors and gases discharged during motor vehicle fueling; B. Preventing their emission into the atmosphere; and C. Maintaining ninety-five percent (95%) efficiency of total capture and emission reduction. 2. After January 1, 1999, no installation subject to this section shall employ remote vapor check valves. 3. After January 1, 1999, no construction permit formodification or replacement of any equipment or component, including a like for like replacement, shall be approved unless the equipment or component is MO/PETP approved. After January 1, 1999, if a construction permit is not required, no installation utilizing an approved system shall modify or replace any equipment or component, including a like for like replacement, unless the equipment or component is MO/PETP approved. In the event that the staff director finds a violation of this provision, the staff director may require replacement of components or equipment with MO/PETP approved components or equipment. 4. For the purpose of subsection (3)(E) of this rule, no vapor recovery systems or devices shall be installed, used ormaintained until they are permitted by the director in accordance with subsections (3)(H) and (I) of this rule. 5. All tank gauging and sampling sites or ports, valves, breakaways, joints and disconnects on the vapor recovery systems shall be gas-tight to prevent VOC emissions except during gauging or sampling. 6. All vapor recovery systems shall be maintained in good working order in accordance with the manufacturer’s specifications and with no indication of visible liquid leaks. 7. The operator of each affected installation shall postoperation instructions conspicuously in the gasoline dispensing area for the system in use at each station. Theinstructions shall clearly describe how to fuel vehicles correctly with vapor recovery nozzles utilized at that station. The instructions shall also include a warning that repeated attempts to continue dispensing gasoline after the system has indicated that the vehicle fuel tank is full may result in spillage of gasoline. 8. The operator of each affected installation shall ensure dispensing gasoline meets the requirements of 40 CFR80.22(j) promulgated June 26, 1996 and hereby incorporated by reference in this rule, as published by the Office of Federal Register, U.S. National Archives and Records, 700 Pennsylvania Avenue NW, Washington, D.C. 20408. This rule does not incorporate any subsequent amendments or additions. 9. The staff director shall identify and list specificdefects that substantially impair the effectiveness of components or systems used for the control of gasoline vaporsresulting from motor vehicle fueling operations. This ongoing list shall be used by the staff director as a basis for marking the components or systems out-of-order and shall bemade available to any gasoline dispensing installations subject to paragraph (3)(E)1. of this rule. The list shall be made available to the installation’s designated person for use in performing system maintenance. 10. Upon the staff director’s identification of substantialdefects in equipment or installation of a gasoline vapor control system, the system or components shall be marked “out-of-order” and no person shall use or permit the use of that system or component until those defects and all other defects have been repaired, replaced or adjusted to establish compliance. The components or system may be released intooperation when the staff director has reinspected the installation; found the system and components to be in good working order; and removed the “out-of-order” notice. Thestaff director shall reinspect the previously marked “out-oforder” system or component and other noted defects as expeditiously as possible after notification from the ope rator that the repairs have been completed. In no case shall the reinspection be more than four (4) business days from the operator’s notification that the repairs have been completed.In those cases in which the reinspection cannot be scheduled within the required time, the owner or operator may remove the “out-of-order” notice with permission of the staff director. If reinspection reveals that compliance has not been established, the system or components shall remaintagged “out-of-order.” The staff director shall conduct a second reinspection within seven (7) business days from the operator’s notification that repairs have been completed.] 1. GDFs not equipped with a Stage II vapor recovery system. Owners or operators shall— A. Employ vapor-tight tank gauging and sampling sites or ports, valves, breakaways, joints, and disconnects on the vaporrecovery systems to prevent emissions of volatile organic compounds except during gauging or sampling; andB. Ensure that motor vehicle refueling meets the requirements of 40 CFR 80.22(j) promulgated June 26, 1996, and hereby incorporated by reference in this rule, as published by the Office of Federal Register, U.S. National Archives and Records, 700 Pennsylvania Avenue NW, Washington, D.C. 20408. This rule does not incorporate any subsequent amendments or additions. 2. GDFs equipped with a Stage II vapor recovery system.

A. Owners or operators shall—

(I) Comply with the requirements of subparagraphs (3)(E)1.A.–B. of this rule. (II) Maintain the Stage II vapor recovery system in goodworking order in accordance with the manufacturer’s specifications and with no indication of visible liquid leaks. Vapor recovery system components may only be replaced with components that have equivalent performance; (III) Post operation instructions conspicuously in the gasoline dispensing area for the vapor recovery system in use at each GDF. The instructions shall clearly describe how to fuel vehicles correctly with vapor recovery nozzles utilized at thatGDF. The instructions shall also include a warning that repeated attempts to continue dispensing gasoline after the system has indicated that the vehicle fuel tank is full may result in spillage of gasoline; (IV) Decommission the Stage II vapor recovery system no later than December 31, 2015. The decommissioning must be performed in accordance with the department’s Stage II Decommissioning Checklist. B. The staff director shall identify and list specific defects 

## Page 772 Proposed Rules April 1, 2014 Vol. 39, No. 7that substantially impair the effectiveness of components or systems used for the control of gasoline vapors resulting from motor vehicle fueling operations. This ongoing list shall be used by the staff director as a basis for marking the components or systems out-of-order and shall be made available to any GDF with a Stage II vapor recovery system in place. C. Upon the staff director’s identification of substantial defects in equipment or installation of a Stage II vapor recoverysystem, the system or components shall be marked “out-oforder” and no person shall use or permit the use of that system or component until those defects and all other defects have been repaired, replaced, or adjusted to establish compliance. The components or system may be released into operation when the staff director has reinspected the installation; found the system and components to be in good working order; and removed the“out-of-order” notice. The staff director shall reinspect the previously marked “out-of-order” system or component and other noted defects as expeditiously as possible after notification from the operator that the repairs have been completed. In no case shall the reinspection be more than four (4) business days from the operator’s notification that the repairs have been completed. In those cases in which the reinspection cannot be scheduled within the required time, the owner or operator may remove the “out-of-order” notice with permission of the staff director. If reinspection reveals that compliance has not been established, the system or components shall remain tagged “out-of-order.” The staff director shall conduct a second reinspection within seven (7) business days from the operator’s notification that repairs have been completed. 3. After the effective date of this rule, no owner or operator of a GDF may install a new Stage II vapor recovery system.

[(F) Initial Fueling of Motor Vehicles. 1. Initial fueling systems and ancillary refueling systems.

A. Subsection (3)(F) of this rule shall only apply to the fueling systems used for the initial fueling of motor vehicles as defined in subsection (2)(E) of this rule and the ancillary refueling systems used to fuel in-use motor vehicles defined in subsection (2)(A) of this rule. These initial fueling systems and ancillary refueling systems are not subject to theMO/PETP testing requirements. All other MO/PETP provisions apply. B. The initial fueling systems and ancillary refueling systems storage tank systems are subject to the gasoline storage tank transfer requirements in subsection (3)(C) of this rule except for the MO/PETP testing requirements. All other MO/PETP provisions in subsection (3)(C) of this rule apply. 2. Owner or operator requirements.

A. No owner or operator shall install, permit the use of,or maintain any stationary gasoline tank for the purpose of initial fueling of new motor vehicle gasoline tanks unless the new motor vehicle is equipped with a U.S. Environmental Protection Agency (EPA) certified Onboard Refueling Vapor Recovery (ORVR) system or the gasoline dispensing system isequipped with a vapor recovery system, (e.g., Stage II), capable of a minimum ninety-five percent (95%) control efficiency. B. No owner or operator shall install, permit the use of, or maintain any stationary gasoline tank for the purposeof ancillary fueling of motor vehicles unless the motor vehicle is equipped with an EPA certified ORVR system or thegasoline dispensing system is equipped with a vapor recovery system, (e.g., Stage II), capable of a minimum ninetyfive percent (95%) control efficiency. C. Demonstration of emission capture efficiency of the gasoline dispensing vapor recovery system shall be required and made available to the staff director upon request. The dispensing system, (e.g., Stage II), shall be approved by the staff director if the system— (I) Collects the hydrocarbon vapors and gases discharged during initial motor vehicle fueling; (II) Prevents their emission into the atmosphere; and (III) Demonstrates a minimum of ninety-five percent(95%) control efficiency for emission reduction of the fueling and dispensing operation emissions. Testing methods shall be inaccordance with EPA reference test methods (or alternative test methods as approved by the staff director) for incineration destruction efficiency.D. Initial fueling systems and ancillary refueling systems are subject to the gasoline transfer tank requirementsin subsection (3)(C) of this rule except for the MO/PETP testing. E. The owner or operator of an initial fueling system and ancillary refueling system shall—(I) Maintain the vapor control system in good working order in accordance with the manufacturer’s specifications and with no indications of visible liquid leaks or detectable vapor emissions;(II) Conduct regular preventive maintenance selfinspections of the vapor control system and conduct any necessary repairs upon identification of those defects. Theinstallation must conduct all maintenance specified by manufacturer guidelines. These manufacturers guidelines must be made available to department and local agency inspectors upon request; (III) Ensure all fueling procedures are conducted in the most efficient manner to reduce emissions from drips; and (IV) Ensure the sealing of the filled vehicle’s tank after fueling.F. Reporting and record keeping shall be per subsection (4)(E) of this rule.]

[(G)] (F) Permits Required. 1. [All installations subject to paragraph (3)(E)1. of this rule, except installations subject to subsection (3)(F) of this rule, shall meet the following permitting requirements:] No owner or operator of a GDF subject to subsections (3)(C) or (3)(E) of this rule may construct or modify a Stage I or Stage II vapor recovery system without obtaining a construction permit according to subsection (3)(G) of this rule; and [A. No installation shall construct or undergo vapor recovery system modification without permits obtained according to subsection (3)(H) of this rule; and B. No installation shall operate without an operating permit obtained according to subsection (3)(I) of this rule.] 2. [All installations subject to subsection (3)(F) of this rule shall meet the following permitting requirements:] No owner or operator of a GDF subject to subsections (3)(C) or (3)(E) of this rule shall operate without an operating permit obtained according to subsection (3)(H) of this rule.[A. The installation must apply for a Stage II construction permit for all modifications or construction of initial fueling systems or ancillary refueling systems. All performance testing in subsections (3)(H) and (3)(I) of this rule shall be conducted to ensure system integrity; and B. All operating permitting requirements of subsection (3)(I) of this rule, except paragraph (3)(I)2. of this rule, are applicable to any initial fueling systems or ancillary refueling systems. Except for the initial Stage II Operating Permit, Stage II Operating Permits shall be incorporated as part of the installation applicable requirements of Part 70 Operating Permits according to 10 CSR 10-6.065.]

[(H)] (G) [Construction Permits for Vapor Recovery Systems for New Installations and Vapor Recovery SystemModification for Existing Installations. No new gasoline dispensing installation that requires a Stage II vapor recoverysystem shall begin construction prior to obtaining a construction permit according to paragraph (3)(H)1. of this rule. 

## Page 773 April 1, 2014 Vol. 39, No. 7 

### Missouri RegisterInstallations shall apply for permits to test experimental technology according to paragraph (3)(H)2. of this rule. Existing installations that undergo vapor recovery system modification shall obtain permits according to paragraph (3)(H)3. of this rule. Owners, ope rators and contractors beginning construction without first obtaining a construction permit are subject to enforcement action] Construction Permits for Vapor Recovery Systems for New GDFs and Vapor Recovery System Modification for Existing GDFs. An owner or operator shall not construct a new GDF that requires a Stage I vapor recovery system prior to obtaining a construction permitaccording to paragraph (3)(G)1. of this rule. An owner or operator of an existing GDF shall not modify a vapor recovery system prior to obtaining a construction permit according to paragraph (3)(G)3. of this rule. Owners, operators, or contractors beginningconstruction or modification without first obtaining a construction permit are subject to enforcement action

. 1. [Owners or ope rators of new gasoline dispensing installations that require Stage II equipment shall] An owner or operator planning to construct a new GDF that requires a Stage I vapor recovery system subject to subsections (3)(C) or (3)(E) of this rule shall

—A. Submit an application on a form supplied by the department for a permit to construct at least [sixty (60)] thirty (30) days prior to beginning construction. The application shall include: (I) Complete diagrams and a thorough description of the planned installation; (II) [Plumbing diagrams including vapor lines, vent lines, slope of return vapor lines, material of all underground,above ground and dispenser plumbing, grade of site in relation to tanks, plumbing, and dispensers] Plumbing diagramsincluding vent lines and material of all underground and aboveground plumbing ; (III) [Current CARB executive orders for the proposed system and/or the system components. After January1, 1998, no installation shall be issued a construction permit unless the system that will be installed has been demonstrated to achieve ninety-five percent (95%) efficiency according to paragraph (3)(E)1. of this rule. After January 1, 1999, no installation shall be issued a construction permitunless the equipment and components of the approved system that will be installed have been MO/PETP tested and approved] For gasoline sto rage tanks subject to paragraph(3)(C)2. of this rule, current CARB Executive Orders for the proposed Stage I vapor recovery system ; (IV) [At the option of the owner/ope rator, full port ball valves may be installed just below the riser of the vapor chamber. The ball valves shall be sealed fully open at all times except during testing. The ball valve shall be tested in line during the dynamic back pressure blockage test;] Detailed description of the sto rage tank(s); and (V) [Detailed description of the storage tank(s). The storage tank(s) shall be—] Schedule of construction.[(a) Type I tank(s). A Type I tank is an underground storage tank that shall be covered with not less than six inches (6”) of soil and/or concrete; or (b) Type II tank(s). A Type II tank is one that has any portion of the shell exposed to the atmosphere. A Type II tank shall be equipped with a vapor processor; and (VI) Schedule of construction;]B. Obtain a construction permit prior to beginning construction. The director shall issue a construction permit or a permit rejection [within thirty (30) days of] after receipt of the application [.When an appeal is made following rejection of the application to construct, that appeal shall be filed within thirty (30) days of the notice of rejection] ; C. Display the construction permit in a prominent location during construction; [D. Notify the department seven (7) calendar daysprior to the anticipated completion date of underground piping and schedule a mutually acceptable inspection date. In the event that no mutually acceptable date is available, thestaff director shall schedule the inspection date. The underground piping shall not be covered without visual inspection by the staff director. If defects are found, the staff director shall provide written notice of those defects;] [E.] D. Establish compliance with all rules and requirements of [the department including those in] Division 10 of Title 10 of the Code of State Regulations ; [F. Document for the staff director that prior to the introduction of product, the tank and piping system were subjected to a construction pressurization test of not more than five pounds per square inch (5 psi) and not less than four and five-tenths pounds per square inch (4.5 psi) andmaintained this pressure for not less than thirty (30) minutes;] [G.] E. Obtain staff director approval of final test methods and procedures that will be used to [prove] demonstrate compliance; [H.] F. [Within thirty (30) days of completion of construction, conduct and pass final leak tests and dynamic back pressure/liquid blockage tests to show compliance with department requirements. The staff director may observe the test] Meet the testing requirements in subparagraph (3)(H)1.B. of this rule ; and [I.] G. Obtain and maintain on-site in a prominent location thecurrent operating permit from the director for the site and the specific vapor recovery system that was installed. The operating permit [is renewable every five (5) years and] shall be maintained according to subsection [(3)(I)] (3)(H) of this rule. 2. The director may approve Stage I experimental technology for a specific [gasoline dispensing installation] GDF . Experimental technology may be approved for up to [one (1)] three (3) year s for a limited number of [stations] GDFs under specific conditions determined by the staff director. [Installations] GDFs applying for approval of experimental technology shall— A. Submit an application for director approval at least ninety (90) days prior to beginning construction. The application shall include, but not be limited to: (I) Complete diagrams and a thorough description of the planned installation; (II) [Plumbing diagrams including vapor lines, vent lines, slope of return vapor lines, material of all underground,above ground and dispenser plumbing, grade of site in relation to tanks, plumbing, and dispensers] Plumbing diagramsincluding vent lines and material of all underground and aboveground plumbing ; and (III) Standards, test data, history, and related information for the proposed system;B. Submit to the staff director a detailed plan for the construction and operation of the system. The plan shall include a description of the planned testing and record keeping for the [installation] GDF . The director may issue the construction permit when all conditions of the testing [installation] GDF are deemed satisfactory; C. Display the construction permit in a prominent location during construction; D. Install monitoring equipment to prove that the vapor recovery system is leak-tight if requested by the staff director; and E. Upon completion of testing, obtain and maintain on-site in a prominent location a current operating permit from the director for the specific innovative technology that is in operation. The permit shall specify the technology, the location , and the time period the technology will be tested.
3. [Existing installations that are subject to subsection (3)(E) or (3)(F) of this rule and undergo vapor recovery sys tem 

## Page 774 Proposed Rules April 1, 2014 Vol. 39, No. 7modification shall] An owner or operator of an existing GDF subject to subsections (3)(C) or (3)(E) of this rule that undergoes vapor recovery system modification shall

—A. Submit an application on a form supplied by the department for a permit to construct prior to beginning modifications. [After the effective date of this rule, any revision to thedepartment supplied forms will be presented to the regulated community for a forty-five (45)-day comment period.] Applications for construction permits shall be submitted for projects that include, but are not limited to [:] , any modification— (I) [Modifications t] T hat require s breaking concrete in an

area [that may affect] within fifteen (15) feet of the vapor lines or vent lines ; [and] (II) [Modifications that may affect] To the vapor lines or vent lines themselves; (III) That affects the operation of the vapor recovery system; or (IV) That could result in improper functioning of the vapor recovery system; B. [Supply any information required by the staff director for the specific installation. Such information may include, but not be limited to, plumbing diagrams, including vapor lines, vent lines, slope of vapor lines, material of all underground, above ground and dispenser plumbing, grade of site in relation to tanks, plumbing and dispensers, currentCARB executive orders for the proposed system and equipment, and proof of compliance with all rules and requirements of the department including those in Title 10 of the Code of State Regulations] Supply any information requestedby the staff director for the specific installation. Such information may include, but is not limited to, plumbing diagrams, including vapor or vent lines; material of all underground and aboveground plumbing; current CARB executive orders for the proposed vapor recovery system and equipment; and proof of compliance with all rules and requirements of Division 10 of Title 10 of the Code of State Regulations ;C. Obtain a construction permit prior to beginning the modification. Continued operation during the construction requires department approval. The director shall issue a construction permit or a permit rejection [within thirty (30) days of] after receipt of the application [. When an appeal is made following rejection of the application, that appeal shall be filed within thirty (30) days of the notice of rejection] ; D. Display the construction permit in a prominent location during construction; [E. Establish a schedule for inspection and testing as required by the staff director and notify the department seven (7) calendar days prior to the anticipated completiondate of underground piping and schedule a mutually acceptable inspection date. In the event that no mutually acceptable date is available, the staff director shall schedule the inspection date. The underground piping shall not be covered without visual inspection by the staff director. If defects are found, the staff director shall provide written notice of those defects; F. Supply test results to the staff director;G. Receive staff director approval of final test methods and procedures that will be used to prove compliance;] [H.] E. [Within thirty (30) days of completion of construction, conduct and pass final leak tests and dynamic back pressure/liquid blockage tests to show compliance with department requirements. The staff director may observe the tests] Meet the testing requirements in subparagraph (3)(H)1.B. of this rule ; and [I.] F. Upon completion of testing, obtain and display in aprominent location on-site the current operating permit from the director for the specific site and the specific vapor recovery system that was installed. The operating permit shall be maintained according to subsection (3)(H) of this rule. [(I) The operating permit shall be maintained according to subsection (3)(I) of this rule, except paragraph (3)(I)2. of this rule shall not apply to initial fueling systems and ancillary refueling systems at automobile assembly
installations. (II) The operating permit is renewable every five (5)years, except for operating permits covering initial fueling systems and ancillary refueling systems at automobile assembly installations. Automobile assembly installations shall apply for an initial Stage II Operating Permit covering both their initial fueling systems and their ancillary refueling systems that will be current until their Part 70 Operating Permit is renewed. (III) Except for the initial Stage II Operating Permit, the operating permit for automobile assembly installationsthat covers their initial fueling systems and their ancillary refueling systems shall be incorporated as part of the installation applicable requirements of 10 CSR 10-6.065 Operating Permits.]4. Immediate repair or replacement of vapor recovery system components. A. Owners or operators of GDFs that require immediate repair or replacement of vapor recovery system components may request the department expedite the disposition of their permit application. Detailed justification must be provided with the request. Requests for expedited permit application will be reviewed for approval based on, but not limited to, the following necessity criteria:(I) Compliance with local, state, or federal requirements; (II) Ensure minimum interruption of service to customers; or (III) Installation of equipment to reduce emissions from gasoline transfer; andB. Expedited permit disposition shall not be provided simply for the convenience of the owner or operator of the GDF. 5. Emergency Repairs.

A. Owners or operators of GDFs requiring emergency repair or replacement of vapor recovery system components may immediately begin corrective construction without prior approval of a construction permit if the construction is in response to an
accident or event that— (I) Creates an abnormally high threat of fire; (II) Poses an environmental hazard by allowing release of liquid product onto the ground or abnormal release of vapor into the air; and/or (III) Threatens public safety; andB. Owners or operators of GDFs electing to make emergency repair or replacement per subparagraph (3)(G)5.A. of this rule shall contact the department within forty-eight (48) hours of the commencement of the repair or replacement to determine what future action is required for compliance with this rule. 6. Owners or operators of GDFs shall pay the department a fee of one hundred dollars ($100) for each construction permit.

[(I)] (H) Operating Permits [for Existing Installations] . All [existing] owners or operators of installations subject to subsection [(3)(E) or (3)(F)] (3)(C) or (3)(E) of this rule must apply to the director for an operating permit.
1. [Initial operating permits] Completion of construction

. [The term of the initial permit shall be established by the staff director. In order t] T o obtain an operating permit after the completion of construction, the owner or operator of a [n existing installation] GDF shall— A. Apply to the director for an operating permit within [sixty (60) days of the date of the staff director’s notice to apply and test within ninety (90) days of the notice. However, no installation subject to this requirement shall operate after 

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### Missouri RegisterJanuary 1, 1999, without an operating permit] thirty (30) days of construction completion ; [B. Provide documentation that the Stage II system iscertified by CARB as having a vapor recovery or removal efficiency of at least ninety-five percent (95%);] [C.] B. Conduct and pass a department-approved [back pressure blockage test and a department-approved leak] pressure decay test ; pressure/vacuum valve test; and, where a Stage IIvapor recovery system is in place, a dynamic back pressure/liquid bloc kage test . The owner/operator of the [installation] GDF shall schedule the tests and notify the staff director of the test dates at least seven (7) days prior to the testing date. The staff director may observe the tests. The owner/operator of the [installation] GDF shall provide [satisfactory] the test results to the staff director;[D. Designate a person(s) who has attended a department-approved training course for the Stage II equipment that is installed at that installation. A designated person shall be available for consultation to installation personnel and to the department;] [E.] C. Demonstrate that the installation maintains a system of record keeping that meets the staff director’s requirements; and [F.] D. Establish compliance with all rules and requirements of [the Missouri Department of Natural Resources including those in] Division 10 of Title 10 of the Code of State Regulations

.2. Renewal of operating permits. The operating permit is renewable on the date specified in the initial operating permit and for periods of [five (5)] three (3) years after the initial permit term expires. [In order to renew the operating permit an installation shall—]
A. [Apply to the director for renewal of the operating permit and test within ninety (90) days prior to the renewal date;] In order to renew the operating permit the owner or operator of a GDF shall— (I) Apply to the director for renewal of the operating permit and test within ninety (90) days prior to the renewal date; (II) Demonstrate that the GDF maintained all vapor recovery system components in good operating order during the preceding operating permit term including prompt efforts to establish compliance following “out-of-order” notices; (III) Schedule staff director-approved tests prior to the expiration date of the permit, notify the staff director of test dates at least fourteen (14) days prior to test dates, and provide documentation that the vapor recovery system passed the tests;
and (IV) Maintain records according to subsection (4)(D) of this rule. [B. Demonstrate that the installation maintained allsystem components in good operating order during the preceding operating permit term including prompt efforts to establish compliance following “out-of-order” notices; C. Schedule staff director-approved tests prior to the expiration date of the permit, notify the staff director of testdates at least fourteen (14) days prior to test dates and provide documentation that the system passed the tests; D. Maintain records according to subsection (4)(F) of this rule;] [E.] B. Owners or operators of [A] a n installation using a

vapor recovery system that is decertified by CARB shall establish compliance with this rule within one (1) year or by the next renewal date of the operating permit whichever is longer. Failure to establish compliance will result in nonrenewal of the operating permit [; and]

. [F. After January 1, 2001, no operating permit shall be renewed without documentation that the Stage II system
in use at the installation can be demonstrated to achieveninety-five percent (95%) efficiency as specified in paragraph (3)(E)1. of this rule. Replacement of equipment and/or components in place as part of an approved system onJanuary 1, 1999, shall not be required as long as the equipment and/or components pass operating permit tests.] 3. Owners or operators of GDFs shall pay the department a fee of one hundred dollars ($100) for each operating permit.

[(J)] (I) Owner/Operator Compliance. The owner or operator of a vapor recovery system subject to this rule shall— 1. Operate the vapor recovery system and the gasoline loading equipment in a manner that prevents—A. Gauge pressure from exceeding four thousand five hundred (4,500) pascals (eighteen inches (18") of H 2 O) in the delivery vessel; B. A reading equal to or greater than one hundred percent (100%) of the lower explosive limit (LEL), measured as propane at two point five (2.5) centimeters from all points on the perimeter of a potential leak source when measured by the method referenced in 10 CSR 10-6.030(14)(E) during loading or transfer operations; and C. Visible liquid leaks during loading or transfer operations; and 2. Repair and retest within fifteen (15) days, a vapor recovery system that exceeds the limits in paragraph [(3)(J)1.] (3)(I)1. of this rule; and 3. Reporting and record keeping shall be per subsection [(4)(F)] (4)(D) of this rule.

[(K) Vapor Recovery Advisory Group. The St. Louis Vapor Recovery Advisory Group shall advise the staff director on vapor recovery issues in the St. Louis nonattainment area. 1. Composition. The advisory group will consist of one(1) representative from each of these agencies or organizations: A. Missouri Department of Natural Resources, Air Pollution Control Program; B. Missouri Department of Natural Resources, Hazardous Waste Program Underground Storage Tank Unit; C. St. Louis City Air Pollution Control Agency or St. Louis County Air Pollution Control Agency; D. Missouri Department of Agriculture, Division of Weights and Measures; E. An organization representing petroleum marketers; F. An organization representing petroleum equipment contractors; and G. An organization representing oil refiners. 2. Purpose. The St. Louis Vapor Recovery Advisory Group shall review, study and make recommendations to the staff director on vapor recovery issues. Any member of the advisory group may bring an issue to the attention of the group. The advisory group shall— A. Review vapor recovery system components that frequently fail;
B. Review CARB certifications and decertifications of vapor recovery system components; C. Develop modifications to established tests such as the leak decay test and the back pressure blockage test. Modified test procedures shall prove integrity of Stage I andStage II systems but may be designed for cost and time efficiency; and D. Review any other vapor recovery issues deemed appropriate by the staff director. 3. Limitations. The advisory group is subject to all applicable state and federal statutes and regulations. All advisory group meetings shall comply with the Missouri Sunshine Act. The advisory group assumes no regulatory authority.]

(4) Reporting and Record Keeping.

(B) Owners or operators of gasoline loading installations subject

to [gasoline loading] subsection (3)(B) of this rule shall keep complete records documenting the number of delivery vessels loaded andtheir owners. Records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request. 

## Page 776 Proposed Rules April 1, 2014 Vol. 39, No. 7[(C) The owner or operator of stationary storage tanks subject to gasoline transfer subsection (3)(C) of this ruleshall keep records documenting the vessel owners and number of delivery vessels unloaded by each owner. Records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request. The owner or operator shall retain on-site copies of the loading ticket, manifest or delivery receipt for each grade of product received, subject to examination by the staff director uponrequest. If a delivery receipt is retained rather than a manifest or loading ticket, the delivery ticket shall bear the following information: vendor name, date of delivery, quantity of each grade, and the manifest or loading ticket number. The required retention on-site of the loading ticket, manifest or delivery receipt shall be limited to the four (4) most recent records for each grade of product.]

[(D)] (C) Owners or operators of gasoline delivery vessels subject to subsection (3)(D) of this rule shall keep records of all tests and maintenance performed on the vessels. Records shall be kept for two(2) years and made available to the staff director within five (5) business days of a request. Also a copy of the vessel’s current Tank Truck Tightness Test results shall be kept with the delivery vessel at all times and made immediately available to the staff director upon request.

[(E) Initial fueling and ancillary fueling of motor vehicles subject to subsection (3)(F) of this rule shall keep records on-site of all self-tests, self-inspections, defects found, repairs, and maintenance activities. Records shall be kept fortwo (2) years and made available to the staff director within five (5) business days of a request.]

[(F)] (D) Owner/Operator Compliance. The owner or operator of a vapor recovery system subject to subsection [(3)(J)] (3)(C), (3)(E), or (3)(I) of this rule shall maintain records of department permits, inspection reports, enforcement documents, training certifications, gasoline deliveries, routine and unscheduled maintenance , [and] repairs , and all results of tests conducted. Unless otherwise specifiedin this rule, records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request.

(5) Test Methods.

(A) Gasoline Loading. Gasoline loading testing procedures to determine compliance with subparagraph (3)(B)2.A. of this rule shall be according to 10 CSR 10-6.030 subsection (14)(A) or by any method determined by the staff director. The staff director, at any time, may monitor an installation subject to subsection (3)(B) of this rule to confirm compliance with this rule.

(B) Gasoline Delivery Vessels. [Gasoline delivery vessels testing and monitoring procedures to determine compliancewith subsection (3)(D) of this rule and confirm the continuing existence of leak-tight conditions shall be according to 10 CSR 10-6.030 subsection (14)(B) or by any method determined by the staff director] Testing procedures for gasoline delivery vessels to determine compliance with subsection(3)(D) of this rule shall be according to 10 CSR 10-6.030 subsection (14)(B) or by any method determined by the staff director. The staff director, at any time, may monitor a gasoline deliveryvessel subject to subsection (3)(D) of this rule to confirm compliance with this rule

.

(C) Fueling of Motor Vehicles and Gasoline Transfer at GDFs

. The staff director, at any time, may monitor a [n installation] GDF subject to subsection (3)(C) or (3)(E) of this rule to confirm compliance with this rule . The staff director may require a leak test, a back pressure bloc kage test, [an air-to-liquid test,] a pressure/vacuum valve test , or may require any test or monitoring procedure in order to determine compliance with this rule.

[(D) Delivery vessel, vapor recovery system or gasoline loading equipment may be monitored by the staff director at any time by a method determined by the staff director to confirm continuing compliance with this rule.(E) An annual staff director-approved back pressure blockage test and/or air-to-liquid test may be required. Additional testing may also be required by the staff director in order to determine proper functioning of vapor recovery equipment.

(F) Installations containing initial fueling systems and ancillary refueling systems shall allow the department tomake vapor recovery inspections at any time to ensure systems are in working order and are being maintained andoperated according to permits and regulations, and manufacturer recommendations— 1. The department and local agency Stage II inspectors shall be allowed access in a timely manner. Department and local agency Stage II inspectors shall make every attempt to avoid disrupting assembly line production. This may be done by allowing initial fueling site personnel to make repairs on the spot, or within a reasonable time frame. However, thisconsideration will not affect recording of defects or enforcement action; and 2. After repairs are made and notification by the plant is received, the department or local agency shall reinspect all defects found in official Stage II inspections. Failure by an installation to notify the department of repairs and request reinspection within fifteen (15) days of repair may result in enforcement action.]

[(G)] (D) All emission controls that are approved by the director will not be considered federally enforceable [,] and will not shield a source from the [federal] obligation to comply with the underlying federal emission controls [, by the EPA] until submitted to EPA and approved by EPA in the state implementation plan.

AUTHORITY: section 643.050, RSMo [2000] Supp. 2013 . Originalrule filed March 14, 1967, effective March 24, 1967. For intervening history, please consult the Code of State Regulations . Amended: Filed Feb. 27, 2014.

PUBLIC COST: This proposed amendment will not cost state agencies or political subdivisions more than five hundred dollars ($500) in the aggregate.

PRIVATE COST: This proposed amendment will save private entities$8,947,500 in aggregate over the life of the rule. See the private entity fiscal note for details of the estimated savings and assumptions used in estimation.

NO TICE OF PUBLIC HEARING AND NO TICE TO SUBMIT COMMENTS: A public hearing on this proposed amendment will begin at 9:00 a.m., May 29, 2014. The public hearing will be held at the Missouri Department of Natural Resources, St. Louis Regional Office, 7545 S. Lindbergh, Suite 220, DESE Conference Room, St. Louis, Missouri. Opportunity to be heard at the hearing shall be afforded any interested person. Interested persons, whether or not heard, may submit a written or email statement of their views until 5:00 p.m., June 5, 2014. Written comments shall be sent to Chief, Air Quality Planning Section, Missouri Department of Natural Resources’ Air Pollution Control Program, PO Box 176, JeffersonCity, MO 65102-0176. Email comments shall be sent to apcprulespn@dnr.mo.gov. 

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## Page 782 Proposed Rulesand possession limits for ducks, geese, and coots are the same as during the regular duck, goose, and coot hunting seasons. Any person fifteen (15) years or younger may participate in the youth waterfowlhunting days without permit provided they are in the immediate presence of an adult eighteen (18) years of age or older. If the youth hunter does not possess a hunter education certificate card, the adult must be properly licensed (i.e., must meet any permit requirements that allows small game hunting) and have in his/her possession a valid hunter education certificate card unless they were born before January 1, 1967. The adult may not hunt ducks but may participate in other seasons that are open on the special youth days;

(L) Persons who possess a valid Conservation Order Permit may chase, pursue, and take blue, snow, and Ross’s geese from one half (1/2) hour before sunrise to one-half (1/2) hour after sunset from February 1, 2015, through April 30, 2015. Any other regulation notwithstanding, methods for the taking of blue, snow, and Ross’s geese include using shotguns capable of holding more than three (3) shells, and with the use or aid of recorded or electrically amplified bird calls or sounds, or recorded or electrically amplified imitations of bird calls or sounds. An exception to the above permit requirement includes any person fifteen (15) years of age or younger, provided either 1) s/he is in the immediate presence of a properly licensed adult (must possess a Conservation Order Permit) who is eighteen (18) years of age or older and has in his/her possession a valid hunter educationcertificate card, or was born before January 1, 1967, or 2) s/he possesses a valid hunter education certificate card. A daily bag limit will not be in effect February 1, 2015, through April 30, 2015 (See 3 CSR 10-5.436 and 3 CSR 10-5.567 for Conservation Order Permit requirements); and

(M) Migratory game birds, to include only doves, ducks, mergansers, and coots, may be taken by hunters with birds of prey as follows (See 3 CSR 10-9.442 for additional provisions about falconry including season lengths and limits for wildlife other than migratory birds. See 3 CSR 10-9.440 for falconry permit requirements): 1. Doves may be taken from September 1 to December 16 from one-half (1/2) hour before sunrise to sunset. Daily limit: three (3)doves; possession limit: nine (9) doves, except that any ducks, mergansers, and coots taken by falconers must be included within these limits; and 2. Ducks, mergansers, and coots may be taken from sunrise to sunset from September 6, 2014, through September 21, 2014,statewide, and from one-half (1/2) hour before sunrise to sunset as follows: in the North Zone, October 18, 2014, through October 19, 2014, October 25, 2014, through December 23, 2014, and February 10, 2015, through March 10, 2015; in the Middle Zone, October 25, 2014, through October 26, 2014, November 1, 2014, through December 30, 2014, and February 10, 2015, through March 10, 2015; and, in the South Zone, November 22, 2014, through November 23, 2014, November 27, 2014, through January 25, 2015, and February10, 2015, through March 10, 2015. Daily limit: three (3) ducks, mergansers, and coots singly or in the aggregate, possession limit: nine (9) ducks, mergansers, and coots singly or in the aggregate, except that any doves taken by falconers must be included within these limits.

SUMMARY OF PUBLIC COMMENTS: Seasons and limits are exempted from the requirement of filing as a proposed amendment under section 536.021, RSMo.

This amendment was filed August 25, 2014, becomes effective September 1, 2014

.



### Title 10—DEPARTMENT OF NATURAL RESOURCES Division 10—Air Conservation Commission Chapter 5—Air Quality Standards and Air Pollution Control Rules Specific to the St. Louis Metropolitan Area

ORDER OF RULEMAKING By the authority vested in the Missouri Air Conservation Commission under section 643.050, RSMo Supp. 2013, the commission amends a rule as follows:

10 CSR 10-5.220 is amended.

A notice of proposed rulemaking containing the text of the proposed amendment was published in the Missouri Register on April 1, 2014 (39 MoReg 769–782). Those sections with changes are reprinted here. This proposed amendment becomes effective thirty (30) days after publication in the Code of State Regulations

.

SUMMARY OF COMMENTS: The Missouri Department ofNatural Resources’ Air Pollution Control Program received seventeen (17) comments from six (6) sources: General Motors Vehicle Manufacturing, Regulatory Environmental Group for Missouri, Missouri Petroleum Marketers & Convenience Store Association (MPCA), Wallis Companies, St. Louis County Air Pollution Control Program, and Missouri Petroleum Sto rage T ank Insurance fund.

Due to the similarity in the following five (5) comments, one (1) response that addresses these comments is presented after the five (5)

comments. COMMENT #1: General Motors commented that they agree withmost of the changes in the proposed amendment, but expressed concerns with the provisions for aboveground sto rage tanks (ASTs) used for initial fueling of motor vehicles, as stated in comment 6 below. COMMENT #2: MPCA supports removal of Stage II requirements and elimination of all reference to the Missouri PerformanceEvaluation Testing Procedures (MOPETP). They expressed appreciation for the ongoing dialogue the department has maintained withMPCA members and other interested parties. They expressed concern with the AST provisions, resolution of the vent cap/vacuumissue, permitting provisions, and permitting fees as stated in comments 8 through 14 below.COMMENT #3: Wallis Companies expressed their thanks and appreciation to the department for their quick, efficient, and systematic removal of Stage II requirements. They thanked the department fortheir ongoing dialogue with industry representative during the rulemaking process. They expressed concern with the AST provisions, resolution of the vent cap/vacuum issue, permitting provisions, and permitting fees as stated in comments 8 through 14 below. COMMENT #4: St. Louis County supports the rule revisions and appreciates the department’s efforts to balance the needs of both the industry and the regulators to ensure the continual environmentalprotection provided by vapor recovery system. They also offered recommended rule language for fueling of motor vehicles at gasolinedispensing facilities (GDFs) and operating permits as stated in comments fifteen (15) through seventeen (17) below. They also supported the oversight provided by the Construction Permitting program. COMMENT #5: The Missouri Petroleum Sto rage T ank Insurance Fund (PSTIF) supports removal of Stage II requirements. They expressed appreciation for the time the department spent discussing the proposed amendment with stakeholders and the department’swillingness to work with interested parties to find reasonable solutions to compliance problems. They expressed concern with the ASTprovisions, resolution of the vent cap/vacuum issue, permitting provisions, and permitting fees as stated in comments 8 through 14 below. RESPONSE: The Missouri Department of Natural Resources’ AirPollution Control Program appreciates the support of the above commenters and will address other noted concerns in comments below.No changes have been made to the rule text as a result of these comments.

COMMENT #6: General Motors commented that they are concerned with the change to paragraph (3)(C)4., which prohibits the use of aboveground gasoline sto rage tanks at gasoline dispensing facilities 

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with a capacity greater than one thousand (1,000) gallons. The General Motors assembly plant uses an initial fueling system with two (2) twenty thousand (20,000) gallon sto rage tanks for initial fueling of vehicles assembled at the plant. The system has been in place as an integral part of the assembly process since the plant was built in the early 1980’s. They believe the proposed language does not take into account their existing tanks, and they provided suggested text changes intended to ensure their tanks will not be prohibited. RESPONSE: The prohibition on ASTs greater than one thousand (1,000) gallons in paragraph (3)(C)4. of the proposed amendment only applies to gasoline dispensing facilities (GDFs) in the St. Louis ozone non-attainment area. ASTs at facilities other than GDFs are not affected by the prohibition. The General Motors assembly plant is not a GDF, therefore the ASTs at that facility are not affected by the prohibition. To clarify the distinction between GDFs and other facilities that operate gasoline dispensers, the definition of Gasoline Dispensing Facility in 10 CSR 10-6.020 Definitions and Common Reference Tables is being revised in a separate rulemaking to clarify that vehicle assembly plants and gasoline distribution facilities are not considered GDFs. The proposed rulemaking that will revise the definition of GDF is tentatively scheduled to be filed with the Secretary of State in late 2014. No changes have been made to the rule text as a result of this comment.

COMMENT #7: The Regulatory Environmental Group for Missouri (REGFORM) commented at the public hearing that a conversation with department staff just prior to the hearing answered questions with respect to the purpose of changes in the proposed amendmentand the impact they will have on commercial gas dispensing facilities. REGFORM stated that the concerns that were going to be raised in a letter in conjunction with a public hearing comment will be held since clarifications being made address those concerns. RESPONSE: Department staff is pleased they were able to allay REGFORM’s concerns about the effect of the proposed amendment changes on commercial gas dispensing facilities. No changes have been made to the rule text as a result of this comment.

COMMENT #8: MPCA, Wallis Companies, and PSTIF commented that the proposed amendment would prohibit aboveground sto rage tanks (ASTs) larger than one thousand (1,000) gallons at gasolinedispensing facilities. This would place a hardship on some businesses that currently have such tanks in use. They requested that DNR “grandfather” all existing aboveground sto rage tanks, as doingso will not cause any deterioration of air quality from what it currently is. In addition, they noted that other metropolitan areas, including East St. Louis, allow installation of new ASTs larger thanone thousand (1,000) gallons for certain commercial/industrial facilities. They requested that the rule be revised to allow for waiver of the prohibition by the DNR on a case-by-case basis. RESPONSE: The current version of the rule does not allow ASTs greater than one thousand (1,000) gallons at GDFs because MOPETP never approved vapor recovery equipment for ASTs. This rulemaking would simply codify this long-standing prohibition. We are not aware of any ASTs at GDFs in the St. Louis area. ASTs at facilities other than GDFs, such as commercial or industrial facilities, are not affected bythe prohibition. Since ASTs inherently emit more volatile organic compounds (VOCs) than equivalent underground tanks, allowing new ASTs above one thousand (1,000) gallons at GDFs would increase emissions, adversely impact air quality in the St. Louis ozone nonattainment area, and jeopardize the U.S. Environmental Protection Agency’s approvalof the revised rule. The Department would be willing to consider allowing California Air Resources Board (CARB) approved, Enhanced Vapor Recovery (EVR) ASTs in a future rulemaking. No changes have been made to the rule text as a result of this comment.

COMMENT #9: MPCA, Wallis Companies, and PSTIF commented that the current requirement specifying use of a pressure/vacuumvalve certified by the CARB at three inches water column pressure/eight inches water column vacuum (3"wcp/8"wcv) does not work in the real world, and owners who meet this requirement areoften then forced into non-compliance with the department’s underground sto rage tank (UST) rules, as the valves cause their automatic tank gauges to malfunction. They do not oppose the requirement that valves have a three inch (3")wcp feature to prevent emission ofvolatile hydrocarbons during fuel delivery, but the vacuum requirement is problematic. They appreciate that the proposed rule attempts to alleviate this problem by stating “Owners and operators of GDFs with monthly throughput greater than one hundred thousand (100,000) gallons may use a vapor recovery system that deviates from the requirements of subparagraph (3)(C)2.A. of this rule only if the vapor recovery system is approved by the director and has a collection efficiency of at least ninety-eight percent (98%).” They stated the proposed language is inadequate because the problem also occurs at some facilities with smaller throughputs and appears to require each tank owner to approach the department individually to request approval of his/her alternate equipment. They requested that, once a particular device has been demonstrated to the department’s satisfaction that it has a collection efficiency of at least ninety-eightpercent (98%), the rule should authorize the director of the department’s Air Pollution Control Program to approve the device one time, after which any UST owner/operator could use that device and be in compliance with the rule. RESPONSE AND EXPLANATION OF CHANGE: The department is aware of the problem of excessive tank vacuum and is committed to working with industry representatives to develop a solution. To allow implementation of a future solution and address the concernsof the commenters, subsection (3)(C) has been revised to include language that would allow the director to approve a vapor recovery system or component that deviates from the requirements of subparagraph (3)(C)2.A. when provided documentation that the system or component has a collection efficiency of at least ninety-eight percent (98%) and that compliance with the requirements of subparagraph (3)(C)2.A. would lead to noncompliance with other state or federal regulations or to improper functioning of the gasoline sto rage tank system. Any approved system or component could then be used at any GDF in the St. Louis area.

COMMENT #10: MPCA, Wallis Companies, and PSTIF commented that they would prefer elimination of the permit requirement for new installations. They noted that the department would still knowof such new installations because the department’s underground storage tank (UST) rules require notification prior to installation and Missouri’s Emergency Planning and Community Right-To-Know Act (EPCRA) requires annual notice of such facilities. They stated the requirement in this rule to obtain a permit prior to undertaking any “modification” of the tank/piping or dispensing equipment creates abarrier to compliance with the UST rules, and requested the proposed amendment be revised so it simply requires the owner/operator to give notice of such work via electronic submission.

RESPONSE AND EXPLANATION OF CHANGE: St. Louis is a nonattainment area for ozone and strict control and oversight of VOC emissions is required by the Missouri State Implementation Plan (SIP). Permitting of new GDFs is a tool for tracking VOC emission sources to assure SIP ozone control requirements are met. Decommissioning of Stage II systems and major modifications at existing GDFs must alsobe approved by the department to ensure no increases in VOC emissions result. Therefore, approved construction permits are required for these activities. As a result of this comment, the department is revising the permitting provisions for minor modifications at existing GDFs toallow for construction permit notifications in place of the full construction permit approval process. This should lessen the burden on owners or operators of existing GDFs making minor modifications that do not have the potential to increase emissions. Specifically, the ruletext in subsection (3)(G) is being revised to require construction permit application and approval for construction of new GDFs, decommissioning of Stage II systems at existing GDFs, and major modifi cations at existing GDFs where the fixed capital costs of the new components will exceed fifty percent (50%) of the fixed capital cost of a 

## Page 1578 Orders of Rulemakingnew gasoline dispensing system. For minor modifications at existing GDFs where the fixed capital costs of the new components will not exceed fifty percent (50%) of the fixed capital cost of a new gasolinedispensing system, the owner or operator would submit a construction permit notification and may then proceed with the modification after submittal of the notification.

COMMENT #11: MPCA, Wallis Companies, and PSTIF commented that they appreciate the effort to accommodate emergencies orother urgent situations, but believe the proposed language is needlessly complex. They requested eliminating paragraph (3)(G)4., as itwould be unnecessary if the department agrees to change the requirement from a permit to a notice when making repairs. They furtherrequested that paragraph (3)(G)5. be made simpler and provided suggested language. RESPONSE AND EXPLANATION OF CHANGE: As explained in the response to comment #10, subsection (3)(G) has been revised to allow owners or operators of GDFs making minor modifications to begin work upon submittal of the construction permit notification. Therefore, the proposed language in paragraph (3)(G)4. is redundant and has been deleted. The emergency repair provision in subsection (3)(G) specifies the conditions that constitute an emergency which requires immediate corrective construction. Simplifying the language by removing the conditions that constitute an emergency may lead to confusion between the regulated community and the department. Therefore, the language for emergency repairs in subsection (3)(G) is being retained as proposed.

COMMENT #12: MPCA, Wallis Companies, and PSTIF commented that subparagraph (3)(G)3.C. eliminates the need for the department to respond to construction permit applications within thirty (30) days. They oppose the change and requested the rule retain the requirement for timely response by the department.
RESPONSE AND EXPLANATION OF CHANGE: Subsection(3)(G) has been revised to add a provision which requires the department to issue a construction permit or a permit rejection within thirty (30) days of receipt of all construction permit applications for construction of a new GDF that requires a Stage I vapor recovery system, decommission of an existing Stage II vapor recovery system, or major modification to an existing GDF.

COMMENT #13: MPCA, Wallis Companies, and PSTIF requested adding language to explicitly state that the owner/operator need not wait for department inspectors to be present to conduct tests after repairs. RESPONSE AND EXPLANATION OF CHANGE: Language has been added to subsection (3)(H) stating that the staff director may observe the test at the completion of repairs, but it is not required that the staff director be present and observe the test.

COMMENT #14: MPCA, Wallis Companies, and PSTIF commented that they strongly believe the fees associated with this rule andproposed amendments should be eliminated or at the very least drastically reduced. They, ho wever, are willing to work with the department on the fee issue assuming the other issues commented on are equitably resolved.RESPONSE: The proposed amendment codifies the present one hundred dollar ($100) permitting fee and does not constitute a fee increase for stakeholders. These fees are necessary to help fund the department’s vapor recovery activities. As noted in the Private Entity Fiscal Note, the overall financial impact on GDFs in the St. Louisarea is overwhelmingly positive due to the elimination of Stage II systems, which are expensive to install and maintain. No changes have been made to the rule text as a result of this comment.

COMMENT #15: St. Louis County commented that provisions forfueling of motor vehicles at GDFs in subsection (3)(E) of the proposed amendment do not clearly state the ability of the director to inspect and require repairs of existing Stage I facilities. They suggested rule language to clearly state the department has the ability toinspect Stage I and Stage II vapor recovery systems, add an out-oforder procedure for defective Stage I systems and components similar to that of Stage II systems, and revise the introductory statement. They noted that the recommendations are consistent with current policies and field practices. RESPONSE: The suggested change to the introductory statement has the same meaning as the language proposed and, therefore, no change is needed. The ability of the department to inspect vapor recovery systems is contained in 643.050.1, RSMo and adding rule language to restate this authority is not necessary. The out-of-order procedure for defective Stage II systems in the current rule is present because of the complexity of the systems and their inherently high duty cycle,i.e. they are used at all times during vehicle refueling. Adding a similar out-of-order procedure for defective Stage I systems is not necessary because Stage I systems are much simpler and have low duty cycles, i.e. they are only used during fuel transfer into the sto rage tanks. In addition, facility compliance expectations are outlined in theDepartment’s Operations and Compliance manuals (available publicly on the department’s website) for review. No changes have been made to the rule text as a result of this comment.

COMMENT #16: St. Louis County commented that the operating permit provisions in subsection (3)(H) of the proposed amendment donot clearly state the requirements for testing notification and information required prior to testing. They suggested language to change the notification on post-construction testing from seven (7) days to fourteen (14) days, add a requirement that all testing be conducted in a time frame that allows for department observation of the test, add a provision that the department may reject testing conducted without notice to the department, add a requirement that testing results must be supplied to the department in a specific format within ten (10) days of test completion, clarify the testing requirements for renewal of operating permits, and revise the recordkeeping requirement for operating permits at completion of construction.RESPONSE AND EXPLANATION OF CHANGE: With the exception of revising the recordkeeping requirements for operating permits at the completion of construction, the changes suggested by St. Louis County either restate current permitting policies and practices or increase the regulatory burden on owners or operators of GDFs. The suggested revision to the recordkeeping requirements at completion of construction removes any ambiguity in the requirements by citing specific rule requirements instead of relying on department approval. Therefore, the recordkeeping requirements for operating permits atcompletion of construction has been revised to state that the requirements of subsection (4)(D) of the rule must be met instead of meeting the staff director’s requirements. The other requirements suggested by St. Louis County are not being added to the rule because the benefits derived by the department do not justify the additional regulatory burden and bureaucracy placed on the regulated entities.

COMMENT #17: St. Louis County commented that they support proposed language in subsection (3)(G) allowing for immediate repair or replacement and emergency repairs to vapor recovery systems. Theproposed amendment clarifies the requirements and defines what constitutes an immediate repair or replacement and an emergency.RESPONSE: The provisions for emergency repairs are retained as proposed. The provisions for immediate repair or replacement have beenremoved since they are no longer needed with the changes in subsection (3)(G) that allow for construction permit notification for minor modification. No changes have been made to the rule text as a result of this comment.

10 CSR 10-5.220 Control of Petroleum Liquid Sto rage, Loading and Transfer

(3) General Provisions. 

## Page 1579 October 1, 2014 Vol. 39, No. 19 

### Missouri RegisterOctober 1, 2014 Vol. 39, No. 19

(C) Gasoline Transfer at GDFs.

1. No owner or operator of a gasoline sto rage tank or delivery vessel shall cause or permit the transfer of gasoline from a delivery vessel into a gasoline sto rage tank with a capacity greater than five hundred (500) gallons and less than or equal to one thousand (1,000) gallons unless— A. The gasoline sto rage tank is equipped with a submergedfill pipe extending unrestricted to within six inches (6") of the bottom of the tank and not touching the bottom of the tank, or the storage tank is equipped with a system that allows a bottom fill condition; B. All gasoline sto rage tank caps and fittings are vapor-tight when gasoline transfer is not taking place; and C. Each gasoline sto rage tank is vented via a conduit that is—

(I) At least two inches (2") inside diameter; and (II) At least twelve feet (12') in height above grade; and (III) Equipped with a pressure/vacuum valve that is certified by the California Air Resources Board (CARB) at three inches water column pressure/eight inches water column vacuum (3"wcp/8"wcv) except when the owner or operator provides documentation that the vapor recovery system is CARB-certified for a different valve and will not function properly with a 3"wcp/8"wcv valve. 2. No owner or operator of a gasoline sto rage tank or delivery vessel shall cause or permit the transfer of gasoline from a delivery vessel into a gasoline sto rage tank with a capacity greater than one thousand (1,000) and less than forty thousand (40,000) gallons unless— A. The gasoline sto rage tank is equipped with a Stage I vaporrecovery system that is certified by a CARB Executive Order as having a collection efficiency of at least ninety-eight percent (98%); B. The delivery vessel to these tanks is in compliance with subsection (3)(D) of this rule; C. All vapor ports are poppeted fittings; D. The delivery vessel is reloaded at installations complying with the provisions of subsection (3)(B) of this rule; E. The vapor recovery system employs one (1) vapor line per product line during the transfer. The staff director may approve other delivery systems submitted to the department with test data demonstrating compliance with subparagraph (3)(C)2.A. of this rule;F. All vapor hoses are at least three inches (3") inside diameter; and G. All product hoses are less than or equal to four inches (4") inside diameter.3. The director may approve a vapor recovery system or component that deviates from the requirements of subparagraph (3)(C)2.A. of this rule when provided documentation that— A. The system or component has a collection efficiency of at least ninety-eight percent (98%); and B. Compliance with the requirements of subparagraph (3)(C)2.A.of this rule would lead to noncompliance with other state or federal regulations or to improper functioning of the gasoline sto rage tank system. 4. Aboveground gasoline sto rage tanks at GDFs shall not have a capacity greater than one thousand (1,000) gallons. 5. This subsection does not prohibit safety valves or other devices required by government regulations.

(G) Construction Permits for Vapor Recovery Systems for New GDFs, Vapor Recovery System Modification for Existing GDFs, and Stage I experimental technology. 1. Construction of a new GDF that requires a Stage I vapor recovery system, decommission of an existing Stage II vapor recoverysystem, or major modification to an existing GDF. An owner or operator constructing a new GDF that requires a Stage I vapor recovery system, decommissioning an existing Stage II vapor recovery system, or modifying an existing vapor recovery system such that the fixed capital costs of the new components will exceed fifty percent (50%)of the fixed capital cost of a new gasoline dispensing system (including only those components directly related to gasoline dispensing and storage) shall—A. Submit an application on a form supplied by the department for a permit to construct at least thirty (30) days prior to beginning construction. The application shall include: (I) Complete diagrams and a thorough description of the planned installation; (II) Plumbing diagrams including vent lines and material of all underground and aboveground plumbing; (III) For gasoline sto rage tanks subject to paragraph (3)(C)2. of this rule, current CARB Executive Orders for the proposed Stage I vapor recovery system; (IV) Detailed description of the sto rage tank(s); and (V) Schedule of construction;B. Obtain a construction permit prior to beginning construction; C. Display the construction permit in a prominent location during construction; D. Establish compliance with all rules and requirements of Division 10 of Title 10 of the Code of State Regulations ; E. Obtain staff director approval of final test methods and procedures that will be used to demonstrate compliance; F. Meet the testing requirements in subparagraph (3)(H)1.B. of this rule; and G. Obtain and maintain on-site, in a prominent location, thecurrent operating permit from the director for the site and the specific vapor recovery system that was installed. The operating permit shall be maintained according to subsection (3)(H) of this rule. 2. Minor modification to existing GDF. An owner or operator of an existing GDF modifying an existing vapor recovery system such that the fixed capital costs of the new components will not exceedfifty percent (50%) of the fixed capital cost of a new gasoline dispensing system (including only those components directly related to gasoline dispensing and storage) shall—A. Submit a construction permit notification prior to construction for projects that include, but are not limited to, any modification that— (I) Requires breaking concrete in an area within fifteen (15) feet of the vapor lines or vent lines; (II) Modifies vapor lines or vent lines themselves; (III) Affects the operation of the vapor recovery system; or (IV) Could result in improper functioning of the vapor recovery system; B. Supply any information requested by the staff director for the specific installation. Such information may include, but is notlimited to, plumbing diagrams, including vapor or vent lines; material of all underground and aboveground plumbing; current CARBexecutive orders for the proposed vapor recovery system and equipment; and proof of compliance with all rules and requirements of Division 10 of Title 10 of the Code of State Regulations ; C. Modify the vapor recovery system in accordance with the rules and requirements of Division 10 of Title 10 of the Code of State Regulations . If, after review of the application, or inspection of the modification to the vapor recovery system, it is discovered that the modification is not in compliance with the rules and requirements of Division 10 of Title 10 of the Code of State Regulations , the owner or operator will be subject to enforcement action, and must bring the facility back into compliance with the rules and requirements of Division 10 of Title 10 of the Code of State Regulations ; D. Meet the testing requirements in paragraph (3)(H)1. of this rule; and E. Upon completion of testing, obtain and display, in a prominent location, on-site the current operating permit from the director for the specific site and the specific vapor recovery systemthat was installed. The operating permit shall be maintained according to subsection (3)(H) of this rule. 3. Experimental Stage I technology. The director may approve Stage I experimental technology for a specific GDF. Experimental technology may be approved for up to three (3) years for a limited 

## Page 1580 Orders of Rulemaking

## Page 1581 October 1, 2014 Vol. 39, No. 19 

### Missouri Register

number of GDFs under specific conditions determined by the staff director. GDFs applying for approval of experimental technology shall— A. Submit an application for director approval at least ninety (90) days prior to beginning construction. The application shall include, but not be limited to: (I) Complete diagrams and a thorough description of the planned installation; (II) Plumbing diagrams including vent lines and material of all underground and aboveground plumbing; and (III) Standards, test data, history, and related information for the proposed system;B. Submit to the staff director a detailed plan for the construction and operation of the system. The plan shall include a description of the planned testing and record keeping for the GDF. The director may issue the construction permit when all conditions of the testing GDF are deemed satisfactory; C. Display the construction permit in a prominent location during construction; D. Install monitoring equipment to prove that the vapor recovery system is leak-tight if requested by the staff director; and E. Upon completion of testing, obtain and maintain on-site, in a prominent location, a current operating permit from the directorfor the specific innovative technology that is in operation. The permit shall specify the technology, the location, and the time period the technology will be tested. 4. Emergency Repairs.

A. Owners or operators of GDFs requiring emergency repairor replacement of vapor recovery system components may immediately begin corrective construction if the construction is in response to an accident or event that— (I) Creates an abnormally high threat of fire; (II) Poses an environmental hazard by allowing release of liquid product onto the ground or abnormal release of vapor into the air; and/or (III) Threatens public safety; and B. Owners or operators of GDFs electing to make emergency repair or replacement per subparagraph (3)(G)4.A. of this rule shallcontact the department within forty-eight (48) hours of the commencement of the repair or replacement to determine what future action is required for compliance with this rule. 5. Owners or operators of GDFs making minor modificationsper paragraph (3)(G)2. of this rule may begin modification upon submittal of the construction permit notification. 6. The director shall issue a construction permit or a permit rejection within thirty (30) days of receipt of all construction permit applications submitted per paragraph (3)(G)1. of this rule. 7. Owners or operators of GDFs shall pay the department a feeof one hundred dollars ($100) for each construction permit application submitted in accordance with subsection (3)(G) of this rule.

(H) Operating Permits. All owners or operators of installations subject to subsection (3)(C) or (3)(E) of this rule shall apply to the director for an operating permit. 1. Completion of construction. To obtain an operating permit after the completion of construction, the owner or operator of a GDF shall— A. Apply to the director for an operating permit within thirty (30) days of construction completion; B. Conduct and pass a department-approved pressure decaytest, pressure/vacuum valve test, and, where a Stage II vapor recovery system is in place, a dynamic back pressure/liquid bloc kage test; C. Schedule the test and notify the staff director at least seven (7) days prior to the test date. The staff director may observe the test, but it is not required that the staff director be present and observe the
test; D. Provide the test results to the staff director; E. Demonstrate that the installation maintains a system of record keeping that meets the requirements of subsection (4)(D) of this rule; and F. Establish compliance with all rules and requirements of Division 10 of Title 10 of the Code of State Regulations

.2. Renewal of operating permits. The operating permit is renewable on the date specified in the initial operating permit and for periods of three (3) years after the initial permit term expires. In order to renew the operating permit the owner or operator of a GDF shall— A. Apply to the director for renewal of the operating permit and test within ninety (90) days prior to the renewal date; B. Demonstrate that the GDF maintained all vapor recovery system components in good operating order during the precedingoperating permit term including prompt efforts to establish compliance following “out-of-order” notices; C. Conduct and pass a department-approved pressure decaytest, pressure/vacuum valve test, and, where a Stage II vapor recovery system is in place, a dynamic back pressure/liquid bloc kage test, prior to the expiration date of the permit; D. Schedule the test and notify the staff director at least seven (7) days prior to the test date. The staff director may observe the test, but it is not required that the staff director be present and observe the
test; E. Provide the test results to the staff director; and F. Maintain records according to subsection (4)(D) of this rule. 3. Owners or operators of an installation using a vapor recovery system that is decertified by CARB shall establish compliance withthis rule within one (1) year or by the next renewal date of the operating permit whichever is longer. Failure to establish compliance will result in nonrenewal of the operating permit. 4. Owners or operators of GDFs shall pay the department a fee of one hundred dollars ($100) for each operating permit.



### Title 10—DEPARTMENT OF NATURAL RESOURCES Division 10—Air Conservation Commission Chapter 6—Air Quality Standards, Definitions, Sampling and Reference Methods and Air Pollution Control Regulations for the Entire State of Missouri

ORDER OF RULEMAKING

By the authority vested in the Missouri Air Conservation Commission under section 643.050, RSMo Supp. 2013, the commission amends a rule as follows:

10 CSR 10-6.040 Reference Methods is amended

.
A notice of proposed rulemaking containing the text of the proposed amendment was published in the Missouri Register on April 15, 2014 (39 MoReg 853–854). No changes have been made in the text of the proposed amendment, so it is not reprinted here. This proposed amendment becomes effective thirty (30) days after publication in the Code of State Regulations

.
SUMMARY OF COMMENTS: The Missouri Department of Natural Resources’ Air Pollution Control Program received no comments on the proposed amendment.

## 10 CSR 10-5.220 Control of Petroleum Liquid Storage, Loading

**and Transfer**

(1) Applicability.

(A) This rule shall apply throughout St. Louis City and Jefferson, St. Charles, Franklin and St. Louis Counties.

(B) Compliance with this rule does not relieve the owner or operator of the responsibility to comply with other applicable governmental requirements.

(C) Exemptions to t **T** his r **R** ule include: **and/or Specific**
**Areas of This Rule.**

1. Petroleum storage tanks that meet the following requirements shall be exempt from subsection (3)(A) of this
rule: **Petroleum storage tanks. Subsection (3)(A) of this rule shall not apply to petroleum storage tanks that—** 

A. Are used to s **S** tore processed and/or treated petroleum or condensate when it is stored, processed and/or

treated at a drilling and production installation prior to custody transfer;

B. Contain a petroleum liquid with a true vapor pressure less than 27.6 kilopascals (kPa) (4.0 psia) at ninety degrees Fahrenheit (90°F);

C. Are of welded construction, and equipped with a metallic-type shoe primary seal and have a shoe-mounted secondary seal or closure devices of demonstrated equivalence approved by the staff director; and

D. Are used to s **S** tore waxy, heavy pour crude
oil.

2. Gasoline loading. Subsection (3)(B) of this rule shall not apply to a loading installation whose average monthly throughput of gasoline is less than or equal to one hundred twenty thousand (120,000) gallons when averaged over the most recent calendar year, provided that the installation loads gasoline by submerged loading and meets the following requirements:

## 10 CSR 10-5.220

2 A. To maintain the exemption, these installations shall submit a report on a form supplied by the department no later than February 1 of each year to the staff director stating gasoline throughput for each month of the previous calendar year. After the effective date of this rule, any revision to the department supplied forms will be presented to the regulated community for a forty-five (45)-day comment period; **Subsection (3)(B) of this rule shall not apply to a gasoline loading installation whose average monthly throughput**  **of gasoline is less than or equal to one hundred twenty thousand (120,000) gallons when averaged over the most recent calendar**  **year, provided the gasoline loading installation loads gasoline by submerged filling and—** 

**(I) Owners or operators of gasoline loading installations submit a report to the staff director on a form**  **supplied by the department stating the gasoline throughput for each month of the previous calendar year. The report shall be**  **submitted no later than February 1 of each year;**

**(II) Delivery vessels purchased after December 31, 1995, are Stage I equipped;** 

**(III) Owners or operators of gasoline loading installations maintain records of gasoline throughput**  **and gasoline delivery; and**

**(IV) Delivery vessels operated by an exempt installation do not deliver to Stage I controlled tanks unless**  **the delivery vessel is equipped with and employs Stage I**

**controls.**

B. Delivery vessels purchased after December 31, 1995, shall be Stage I equipped; **A gasoline loading installation that fails to meet the requirements of the**  **exemption in subparagraph (1)(C)2.A. of this rule for one (1) calendar year shall not qualify for the exemption again.** 

C. A loading installation that fails to meet the requirements of the exemption for one (1) calendar year shall not qualify for the exemption again;

D. To maintain the exemption, owners or operators shall maintain records of gasoline throughput and gasoline delivery; and

## 10 CSR 10-5.220

3 E. Delivery vessels operated by an exempt installation shall not deliver to Stage I controlled tanks unless the delivery vessel is equipped with and employs Stage I

controls.

3. **This rule does not apply to** S **s** tationary gasoline tanks with a capacity of less than or equal to five hundred (500) gallons.

4. Fueling of motor vehicles. Installations with one thousand (1,000) gallon or smaller tank(s) and monthly throughput of less than or equal to ten thousand (10,000) gallons of gasoline through the tanks are exempt from subsection (3)(E) of this rule. **Subsection (3)(E) of this rule does not apply to any gasoline dispensing facility (GDF) with one**  **thousand (1,000) gallon or smaller tank(s) and monthly throughput of less than or equal to ten thousand (10,000)**  **gallons of gasoline through the tanks.**

5. Gasoline transfer provisions per paragraph (3)(C)2. of this rule shall not apply to transfers made to storage tanks equipped with floating roofs or their equivalent. **Paragraph (3)(C)2. of this rule does not apply to gasoline transfers made to storage tanks equipped with floating roofs or**  **their equivalent**

6. Gasoline transfer provisions per paragraphs (3)(C)1.–4. of this rule shall not apply to stationary storage tanks having a capacity less than or equal to two thousand (2,000) gallons used exclusively for the fueling of implements of agriculture. **Subsection (3)(C) of this rule does not apply to any storage tank having a capacity less than or equal to two**  **thousand (2,000) gallons used exclusively for the fueling of agricultural equipment.** 

7. Fueling of motor vehicles pursuant to subsection (3)(E) of this rule shall not apply to any stationary tank used primarily for the fueling of agricultural implements or implements of husbandry. For purposes of subsection (3)(E), agricultural implements and implements of husbandry shall refer to vehicles exempted from licensing requirements by the Missouri Department of Revenue. **Subsection (3)(E) of this rule does not apply to any stationary storage tank used primarily for the**  **fueling of agricultural equipment.**

8. Initial fueling of motor vehicles. Subsection (3)(E) of this rule shall not apply to any refueling system used

## 10 CSR 10-5.220

4 for the initial fueling of motor vehicles as defined in subsection (2)(E) of this rule.

9. Ancillary refueling of motor vehicles. Subsection (3)(E) of this rule shall not apply to any ancillary refueling system used for the refueling of motor vehicles as defined in subsection (2)(A) of this rule.

(2) Definitions.

(A) Ancillary refueling system—Any gasoline dispensing installation, including related equipment, that shares a common storage tank with an initial fueling system as defined in subsection (2)(E) of this rule. The purpose of an ancillary refueling system is to refuel in-use motor vehicles at automobile assembly plants. **Agricultural equipment—Any equipment used exclusively for agricultural purposes on land owned or**  **leased for the production of farm products.**

(B) CARB—California Air Resources Board, 2020 L Street,
PO Box 2815, Sacramento, CA 95812.

(C) Department—Missouri Department of Natural Resources, PO Box 176, Jefferson City, MO 65102.

(D) Director—The director of the Missouri Department of Natural Resources, or a designated representative to carry out
the duties as described in 643.060 of the Missouri Air
Conservation Law.

(E) Initial fueling of motor vehicles—The operation, including related equipment, of dispensing gasoline fuel into a newly assembled motor vehicle at an automobile assembly plant while the vehicle is still being assembled on the assembly line. The newly assembled motor vehicles being fueled on the assembly line have fuel tanks that have never before contained gasoline

fuel.

(F) MO/PETP—The Missouri Performance Evaluation Test

Procedures , a set of test procedures for evaluating performance of Stage I/II vapor control equipment and systems to be
installed or that have been installed in Missouri. Contact the department for a copy of the current MO/PETP.

(G) Staff director—Director of the Air Pollution Control Program of the Department of Natural Resources, or a designated representative.

## 10 CSR 10-5.220

5 (H) System—Manufacturer’s application of one of the specific designs for Stage II vapor recovery.

(I) Vapor recovery system modification—Any repair, replacement, alteration or upgrading of Stage I or Stage II vapor recovery equipment or gasoline dispensing equipment equipped with Stage II vapor recovery beyond normal maintenance of the system as permitted by the staff director. Replacement of equipment with like equipment shall not be considered a vapor recovery system modification.

( J **B** ) Definitions of certain terms specified in this rule, other than those defined in this rule section, may be found in

10 CSR 10-6.020.

(3) General Provisions.

(A) Petroleum Storage Tanks.

1. No owner or operator of petroleum storage tanks shall cause or permit the storage in any stationary storage tank of more than forty thousand (40,000) gallons capacity of anypetroleum liquid having a true vapor pressure of one and fivetenths (1.5) pounds per square inch absolute (psia) or greater at ninety degrees Fahrenheit (90°F), unless the storage tank is a pressure tank capable of maintaining working pressures sufficient at all times to prevent volatile organic compound (VOC) vapor or gas loss to the atmosphere or is equipped with one (1) of the following vapor loss control devices:

A. A floating roof, consisting of a pontoon type, double-deck type or internal floating cover or external floating cover, that rests on the surface of the liquid contents and is equipped with a closure seal(s) to close the space between the roof edge and tank wall. Storage tanks with external floating roofs shall meet the additional following requirements:

(I) The storage tank must be fitted with—

(a) A continuous secondary seal extending from the floating roof to the tank wall (rim-mounted secondary seal); or

(b) A closure or other device approved by the staff director that controls VOC emissions with an

## 10 CSR 10-5.220

6 effectiveness equal to or greater than a seal required under subpart (3)(A)1.A.(I)(a) of this rule;

(II) All seal closure devices must meet the following requirements:

(a) There are no visible holes, tears or other openings in the seal(s) or seal fabric;

(b) The seal(s) is intact and uniformly in place around the circumference of the floating roof between the floating roof and the tank wall; and

(c) For vapor-mounted primary seals,the accumulated area of gaps exceeding 0.32 centimeters, oneeighth inch (1/8") width, between the secondary seal and the

tank wall shall not exceed 21.2 cm 2 

## per meter of tank diameter (1.0 in 2 

## per foot of tank diameter);

(III) All openings in the external floating roof, except for automatic bleeder vents, rim space vents and leg sleeves, must be equipped with—

(a) Covers, seals or lids in the closed position except when the openings are in actual use; and

(b) Projections into the tank which remain below the liquid surface at all times;

(IV) Automatic bleeder vents must be closed at all times except when the roof is floated off or landed on the roof leg supports;

(V) Rim vents must be set to open when the roof is being floated off the leg supports or at the manufacturer’s recommended setting; and

(VI) Emergency roof drains must be provided with slotted membrane fabric covers or equivalent covers which cover at least ninety percent (90%) of the area of the opening;

B. A vapor recovery system with all storage tank gauging and sampling devices gas-tight, except when gauging or sampling is taking place. The vapor disposal portion of the vapor recovery system shall consist of an absorber system, condensation system, membrane system or equivalent vapor

## 10 CSR 10-5.220

7 disposal system that processes the vapor and gases from the equipment being controlled; or

C. Other equipment or means of equal efficiency for purposes of air pollution control that may be approved by
the staff director.

2. Control equipment described in subparagraph (3)(A)1.A. of this rule shall not be allowed if the petroleum liquid other than gasoline has a true vapor pressure of 11.1 psia or greater at ninety degrees Fahrenheit (90°F). All storage tank gauging and sampling devices shall be gas-tight except when gauging or sampling is taking place.

3. Reporting and record keeping shall be per subsection (4)(A) of this rule.

(B) Gasoline Loading.

1. No owner or operator of a gasoline loading installation or delivery vessel shall cause or permit the loading of gasoline into any delivery vessel from a gasoline loading installation unless the **gasoline** loading installation is equipped with a vapor recovery system or equivalent. This system or system equivalent shall be approved by the staff director and the delivery vessel shall be in compliance with subsection (3)(D) of this rule.

2. **Gasoline** L **l** oading shall be accomplished in a manner that the displaced vapors and air will be vented only to the vapor recovery system. Measures shall be taken to prevent liquid drainage from the loading device when it is not in use or to accomplish complete drainage before the loading device is disconnected. The vapor disposal portion of the vapor recovery system shall consist of one (1) of the following:

A. An absorber system, condensation system, membrane system or equivalent vapor disposal system that processes the vapors and gases from the equipment being controlled and limits the discharge of VOC into the atmosphere to ten (10) milligrams of VOC vapor per liter of gasoline

loaded;

B. A vapor handling system that directs the vapor to a fuel gas system; or

## 10 CSR 10-5.220

8 C. Other equipment of an efficiency equal to or greater than subparagraph (3)(B)2.A. or B. of this rule if approved by the staff director.

3. Reporting and record keeping shall be per subsecton (4)(B) of this rule.

(C) Gasoline Transfer **at GDFs**

.

1. No owner or operator of a gasoline storage tank or delivery vessel shall cause or permit the transfer of gasoline from a delivery vessel into a gasoline storage tank with a capacity greater than five hundred (500) gallons **and less than or equal to one thousand (1,000) gallons**  unless—

A. The **gasoline** storage tank is equipped with a submerged fill pipe extending unrestricted to within six inches (6") of the bottom of the tank, and not touching the bottom of the tank, or the storage tank is equipped with a system that
allows a bottom fill condition;

B. All **gasoline** storage tank caps and fittings are vapor-tight when gasoline transfer is not taking place; and

C. Each **gasoline** storage tank is vented via a
conduit that is—

(I) At least two inches (2") inside
diameter; and

(II) At least twelve feet (12') in height above grade; and

(III) Equipped with a pressure/vacuum valve that is CARB certified and MO/PETP approved at three inches water column pressure/eight inches water column vacuum (3"wcp/8"wcv) except when the owner or operator provides documentation that the system is CARB certified or MO/PETP approved for a different valve and will not function properly with a 3"wcp/8"wcv valve. Initial fueling of motor vehicle systems and ancillary refueling systems previous MO/PETP approval applies for pressure/vacuum values **Equipped with a pressure/vacuum valve that is certified by the California Air**  **Resources Board (CARB) at three inches water column pressure/eight inches water column vacuum (3"wcp/8"wcv) except**  **when the owner or operator provides documentation that the vapor**

## 10 CSR 10-5.220

9 **recovery system is CARB-certified for a different valve and will not function properly with a 3"wcp/8"wcv valve** 

.

2. Stationary storage tanks having a volume greater than one thousand (1,000) and less than forty thousand (40,000) gallons shall also be equipped with a Stage I vapor recovery system that has a collection efficiency of ninety-eight percent (98%) that is based on MO/PETP, and the delivery vessels to these tanks shall be in compliance with subsection (3)(D) of
this rule. **No owner or operator of a gasoline storage tank or delivery vessel shall cause or permit the transfer of gasoline**  **from a delivery vessel into a gasoline storage tank with a capacity greater than one thousand (1,000) and less than forty**  **thousand (40,000) gallons unless—**

A. The vapor recovery system shall collect no less than ninety-eight percent (98%) by volume of the vapors displaced from the stationary storage tank during gasoline transfer and shall return the vapors via a vapor-tight return line to the delivery vessel. All fill ports and vapor ports shall have Mo/PETP poppeted fittings. **The gasoline storage tank is equipped with a Stage I vapor recovery system that is**  **certified by a CARB Executive Order as having a collection efficiency of at least ninety-eight percent (98%);** 

B. A delivery vessel shall be reloaded only at installations complying with the provisions of subsection (3)(B)
of this rule. **The delivery vessel to these tanks is in compliance with subsection (3)(D) of this rule;** 

C. This subsection shall not be construed to prohibit safety valves or other devices required by governmental regulations. **All vapor ports are poppeted fittings;**

**D. The delivery vessel is reloaded at installations complying with the provisions of subsection (3)(B)**  **of this rule;**

**E. The vapor recovery system employs one (1) vapor line per product line during the transfer. The staff**  **director may approve other delivery systems submitted to the department with test data demonstrating compliance with**  **subparagraph (3)(C)2.A. of this rule;**

**F. All vapor hoses are at least three inches (3") inside diameter; and** 

## 10 CSR 10-5.220

10 **G. All product hoses are less than or equal to four inches (4") inside diameter.** 

3. No owner or operator of a gasoline delivery vessel shall cause or permit the transfer of gasoline from a delivery vessel into a storage tank with a capacity greater than one thousand (1,000) gallons and less than forty thousand (40,000) gallons unless— **The Director may approve a vapor recovery system or component that deviates from the requirements**  **of subparagraph (3)(C)2.A. of this rule when provided**
**documentation that—**

A. The owner or operator employs one (1) vapor line per product line during the transfer. The staff director may approve other delivery systems upon submittal to the department of test data demonstrating compliance with subparagraph (3)(C)2.A. of this rule; **The system or component has a collection efficiency of at least ninety-eight percent (98%);** 

**and**

B. The vapor hose(s) employed is no less than three inches (3") inside diameter; and **Compliance with the requirements of subparagraph (3)(C)2.A.of this rule would lead**  **to noncompliance with other state or federal regulations or to improper functioning of the gasoline storage tank system.** 

C. The product hose(s) employed is no more than four inches (4") inside diameter.

4. Reporting and record keeping shall be per subsection (4)(C) of this rule **Aboveground gasoline storage tanks at GDFs shall not have a capacity greater than one thousand**  **(1,000) gallons**

.

**5. This subsection does not prohibit safety valves or other devices required by government regulations.** 

(D) Gasoline Delivery Vessels.

1. No owner or operator of a gasoline delivery vessel shall operate or use a gasoline delivery vessel which is loaded or unloaded at an installation subject to subsection (3)(B) or (3)(C) of this rule unless—

A. The delivery vessel is tested annually to demonstrate compliance with the test method specified in 40 CFR part 63, subpart R, section 63.425(e);

## 10 CSR 10-5.220

11 B. The owner or operator obtains the completed test results signed by a representative of the testing installation upon successful completion of the leak test. Blank test certification application forms for the test results will be provided to the testing installations by the department. After the effective date of this rule, any revision to the department supplied forms will be presented to the regulated community for a forty-five (45)-day comment period. The owner or operator shall send a copy of the signed successful test results to the staff director. The staff director, upon receipt of acceptable test results, shall issue an official sticker to the owner or operator;

C. The Missouri sticker is placed on the upper left portion of the back end of the vessel; **A copy of the vessel’s current test results are kept with the delivery vessel**  **at all times and made immediately available to the staff director upon request; and** 

D. The delivery vessel is repaired by the owner or operator and retested within fifteen (15) business days of testing if it does not meet the leak test criteria of subparagraph (3)(D)1.A. of this rule; and **The delivery vessel is repaired by the owner or operator and retested within fifteen**  **(15) business days of testing if it does not meet the leak test criteria of subparagraph (3)(D)1.A. of this rule.** 

E. A copy of the vessel’s current Tank Truck Tightness Test results are kept with the delivery vessel at all times and made immediately available to the staff director upon
request.

2. An owner or operator of a gasoline delivery
vessel who can demonstrate to the satisfaction of the staff director that the vessel has passed a current annual leak test
in another state shall be deemed to have satisfied the requirements of subparagraph (3)(D)1.A. of this rule, if the other state’s leak test program requires the same gauge pressure and test procedures as specified in subparagraph (3)(D)1.A. of
this rule. The owner or operator shall apply for a Missouri sticker and display the Missouri sticker on the upper left portion of the back end of the delivery vessel.

3. Reporting and record keeping shall be per **formed as specified in**  subsection (4)( D **C** ) of this rule.

## 10 CSR 10-5.220

12 4. This subsection shall not be construed to **does**

**not** prohibit safety valves or other devices required by governmental safety regulations.

(E) Fueling of Motor Vehicles **at GDFs**

.

1. Except as provided in subsections (3)(A)–(C) of this rule, no owner or operator shall install, permit the use of or maintain any stationary gasoline tank with a capacity of more than one thousand (1,000) gallons or operate an installation with a monthly throughput of greater than ten thousand (10,000) gallons of gasoline through tanks in the one thousand (1,000) gallon or smaller class unless the storage tank(s) is equipped with a vapor recovery system. The system shall be approved by the staff director based on the MO/PETP and shall be capable of—

A. Collecting the hydrocarbon vapors and gases discharged during motor vehicle fueling;

B. Preventing their emission into the atmosphere; and

C. Maintaining ninety-five percent (95%) efficiency of total capture and emission reduction.

2. After January 1, 1999, no installation subject to this section shall employ remote vapor check valves.

3. After January 1, 1999, no construction permit for modification or replacement of any equipment or component, including a like for like replacement, shall be approved unless the equipment or component is MO/PETP approved. After January 1, 1999, if a construction permit is not required, no installation utilizing an approved system shall modify or replace any equipment or component, including a like for like replacement, unless the equipment or component is MO/PETP approved. In the event that the staff director finds a violation of this provision, the staff director may require replacement of components or equipment with MO/PETP approved components or equipment.

4. For the purpose of subsection (3)(E) of this rule, no vapor recovery systems or devices shall be installed, used or maintained until they are permitted by the director in accordance with subsections (3)(H) and (I) of this rule.

## 10 CSR 10-5.220

13 5. All tank gauging and sampling sites or ports, valves, breakaways, joints and disconnects on the vapor recovery systems shall be gas-tight to prevent VOC emissions except during gauging or sampling.

6. All vapor recovery systems shall be maintained in good working order in accordance with the manufacturer’s specifications and with no indication of visible liquid leaks.

7. The operator of each affected installation shall post operation instructions conspicuously in the gasoline dispensing area for the system in use at each station. The instructions shall clearly describe how to fuel vehicles correctly with vapor recovery nozzles utilized at that station. The instructions shall also include a warning that repeated attempts to continue dispensing gasoline after the system has indicated that the vehicle fuel tank is full may result in spillage of gasoline.

8. The operator of each affected installation shall ensure dispensing gasoline meets the requirements of 40 CFR 80.22(j) promulgated June 26, 1996 and hereby incorporated by reference in this rule, as published by the Office of Federal Register, U.S. National Archives and Records, 700 Pennsylvania Avenue NW, Washington, D.C. 20408. This rule does not incorporate any subsequent amendments or additions.

9. The staff director shall identify and list specific defects that substantially impair the effectiveness of components or systems used for the control of gasoline vapors resulting from motor vehicle fueling operations. This ongoing list shall be used by the staff director as a basis for marking the components or systems out-of-order and shall be made available to any gasoline dispensing installations subject to paragraph (3)(E)1. of this rule. The list shall be made available to the installation’s designated person for use in performing system maintenance.

10. Upon the staff director’s identification of substantial defects in equipment or installation of a gasoline vapor control system, the system or components shall be marked “out-of-order” and no person shall use or permit the use of that system or component until those defects and all other defects have been repaired, replaced or adjusted to establish compliance. The components or system may be released into operation when the staff director has reinspected the installation; found the system and components to be in good

## 10 CSR 10-5.220

14 working order; and removed the “out-of-order” notice. The staff director shall reinspect the previously marked “out-of-order” system or component and other noted defects as expeditiously as possible after notification from the operator that the repairs have been completed. In no case shall the reinspection be more than four (4) business days from the operator’s notification that the repairs have been completed. In those cases in which the reinspection cannot be scheduled within the required time, the owner or operator may remove the “out-of-order” notice with permission of the staff director. If reinspection reveals that compliance has not been established, the system or components shall remain tagged “out-of-order.” The staff director shall conduct a second reinspection within seven (7) business days from the operator’s notification that repairs have been completed.

**1. GDFs not equipped with a Stage II vapor recovery system. Owners or operators shall—** 

**A. Employ vapor-tight tank gauging and sampling sites or ports, valves, breakaways, joints, and disconnects on**  **the vapor recovery systems to prevent emissions of volatile organic compounds except during gauging or sampling; and** 

**B. Ensure that motor vehicle refueling meets the requirements of 40 CFR 80.22(j) promulgated June 26, 1996,**  **and hereby incorporated by reference in this rule, as published by the Office of Federal Register, U.S. National Archives and**  **Records, 700 Pennsylvania Avenue NW, Washington, D.C. 20408. This rule does not incorporate any subsequent amendments or** 
**additions.**

**2. GDFs equipped with a Stage II vapor recovery**
**system.**

**A. Owners or operators shall—**

**(I) Comply with the requirements of subparagraphs (3)(E)1.A.–B. of this rule.** 

**(II) Maintain the Stage II vapor recovery system in good working order in accordance with the**  **manufacturer’s specifications and with no indication of visible liquid leaks. Vapor recovery system components may only be**  **replaced with components that have equivalent performance;**

## 10 CSR 10-5.220

15 **(III) Post operation instructions conspicuously in the gasoline dispensing area for the vapor**  **recovery system in use at each GDF. The instructions shall clearly describe how to fuel vehicles correctly with vapor**  **recovery nozzles utilized at that GDF. The instructions shall also include a warning that repeated attempts to continue**  **dispensing gasoline after the system has indicated that the vehicle fuel tank is full may result in spillage of gasoline;** 

**(IV) Decommission the Stage II vapor recovery system no later than December 31, 2015. The**  **decommissioning must be performed in accordance with the department’s Stage II Decommissioning Checklist.** 

**B. The staff director shall identify and list specific defects that substantially impair the effectiveness of**  **components or systems used for the control of gasoline vapors resulting from motor vehicle fueling operations. This ongoing**  **list shall be used by the staff director as a basis for marking the components or systems out-of-order and shall be made**  **available to any GDF with a Stage II vapor recovery system in place.** 

**C. Upon the staff director’s identification of substantial defects in equipment or installation of a Stage II**  **vapor recovery system, the system or components shall be marked “out-of-order” and no person shall use or permit the use of that**  **system or component until those defects and all other defects have been repaired, replaced, or adjusted to establish**  **compliance. The components or system may be released into operation when the staff director has reinspected the**  **installation; found the system and components to be in good working order; and removed the “out-of-order” notice. The staff**  **director shall reinspect the previously marked “out-of-order” system or component and other noted defects as expeditiously as**  **possible after notification from the operator that the repairs have been completed. In no case shall the reinspection be more**  **than four (4) business days from the operator’s notification that the repairs have been completed. In those cases in which**  **the reinspection cannot be scheduled within the required time, the owner or operator may remove the “out-of-order” notice with**  **permission of the staff director. If reinspection reveals that compliance has not been established, the system or components**  **shall remain tagged “out-of-order.” The staff director shall conduct a second reinspection within seven (7) business days**  **from the operator’s notification that repairs have been completed.** 

## 10 CSR 10-5.220

16 **3. After the effective date of this rule, no owner or operator of a GDF may install a new Stage II vapor recovery** 
**system.**

(F) Initial Fueling of Motor Vehicles.

1. Initial fueling systems and ancillary refueling
systems.

A. Subsection (3)(F) of this rule shall only apply to the fueling systems used for the initial fueling of motor vehicles as defined in subsection (2)(E) of this rule and the ancillary refueling systems used to fuel in-use motor vehicles defined in subsection (2)(A) of this rule. These initial fueling systems and ancillary refueling systems are not subject to the MO/PETP testing requirements. All other MO/PETP provisions apply.

B. The initial fueling systems and ancillary refueling systems storage tank systems are subject to the gasoline storage tank transfer requirements in subsection (3)(C) of this rule except for the MO/PETP testing requirements. All other MO/PETP provisions in subsection (3)(C) of this rule apply.

2. Owner or operator requirements.

A. No owner or operator shall install, permit the use of, or maintain any stationary gasoline tank for the purpose of initial fueling of new motor vehicle gasoline tanks unless the new motor vehicle is equipped with a U.S. Environmental Protection Agency (EPA) certified Onboard Refueling Vapor Recovery (ORVR) system or the gasoline dispensing system is equipped with a vapor recovery system, (e.g., Stage II), capable of a minimum ninety-five percent (95%) control efficiency.

B. No owner or operator shall install, permit the use of, or maintain any stationary gasoline tank for the purpose of ancillary fueling of motor vehicles unless the motor vehicle is equipped with an EPA certified ORVR system or the gasoline dispensing system is equipped with a vapor recovery system, (e.g., Stage II), capable of a minimum ninety-five percent (95%) control efficiency.

## 10 CSR 10-5.220

17 C. Demonstration of emission capture efficiency of the gasoline dispensing vapor recovery system shall be required and made available to the staff director upon request. The dispensing system, (e.g., Stage II), shall be approved by the staff director if the system—

(I) Collects the hydrocarbon vapors and gases discharged during initial motor vehicle fueling;

(II) Prevents their emission into the atmosphere; and

(III) Demonstrates a minimum of ninety-five percent (95%) control efficiency for emission reduction of the fueling and dispensing operation emissions. Testing methods shall be in accordance with EPA reference test methods (or alternative test methods as approved by the staff director) for incineration destruction efficiency.

D. Initial fueling systems and ancillary refueling systems are subject to the gasoline transfer tank requirements in subsection (3)(C) of this rule except for the MO/PETP testing.

E. The owner or operator of an initial fueling system and ancillary refueling system shall—

(I) Maintain the vapor control system in good working order in accordance with the manufacturer’s specifications and with no indications of visible liquid leaks or detectable vapor emissions;

(II) Conduct regular preventive maintenance self-inspections of the vapor control system and conduct any necessary repairs upon identification of those defects. The installation must conduct all maintenance specified by manufacturer guidelines. These manufacturers guidelines must be made available to department and local agency inspectors upon
request;

(III) Ensure all fueling procedures are
conducted in the most efficient manner to reduce emissions from drips; and

(IV) Ensure the sealing of the filled vehicle’s tank after fueling.

## 10 CSR 10-5.220

18 F. Reporting and record keeping shall be per subsection (4)(E) of this rule.

( G **F** ) Permits Required.

1. All installations subject to paragraph (3)(E)1. of this rule, except installations subject to subsection (3)(F) of this rule, shall meet the following permitting requirements: **No owner or operator of a GDF subject to subsections (3)(C) or (3)(E) of this rule may construct or modify a Stage I or Stage**  **II vapor recovery system without obtaining a construction permit according to subsection (3)(G) of this rule; and** 

A. No installation shall construct or undergo vapor recovery system modification without permits obtained according to subsection (3)(H) of this rule; and

B. No installation shall operate without an operating permit obtained according to subsection (3)(I) of this

rule.

2. All installations subject to subsection (3)(F) of this rule shall meet the following permitting requirements: **No owner or operator of a GDF subject to subsections (3)(C) or**  **(3)(E) of this rule shall operate without an operating permit obtained according to subsection (3)(H) of this rule.** 

A. The installation must apply for a Stage II construction permit for all modifications or construction of initial fueling systems or ancillary refueling systems. All performance testing in subsections (3)(H) and (3)(I) of this rule shall be conducted to ensure system integrity; and

B. All operating permitting requirements of subsection (3)(I) of this rule, except paragraph (3)(I)2. of this rule, are applicable to any initial fueling systems or ancillary refueling systems. Except for the initial Stage II Operating Permit, Stage II Operating Permits shall be incorporated as part of the installation applicable requirements of Part 70 Operating Permits according to 10 CSR 10-6.065.

(H) Construction Permits for Vapor Recovery Systems for New Installations and Vapor Recovery System Modification for Existing Installations. No new gasoline dispensing installation that requires a Stage II vapor recovery system shall begin construction prior to obtaining a construction permit according to paragraph (3)(H)1. of this rule. Installations shall apply

## 10 CSR 10-5.220

19 for permits to test experimental technology according to paragraph (3)(H)2. this rule. Existing installations that undergo vapor recovery system modification shall obtain permits according to paragraph (3)(H)3. of this rule. Owners, operators and contractors beginning construction without first obtaining a construction permit are subject to enforcement action.

1. Owners or operators of new gasoline dispensing installations that require Stage II equipment shall—

A. Submit an application on a form supplied by the department for a permit to construct at least sixty (60) days prior to beginning construction. The application shall
include:

(I) Complete diagrams and a thorough description of the planned installation;

(II) Plumbing diagrams including vapor lines, vent lines, slope of return vapor lines, material of all underground, above ground and dispenser plumbing, grade of site in relation to tanks, plumbing, and dispensers;

(III) Current CARB executive orders for the proposed system and/or the system components. After January 1, 1998, no installation shall be issued a construction permit unless the system that will be installed has been demonstrated to achieve ninety-five percent (95%) efficiency according to paragraph (3)(E)1. of this rule. After January 1, 1999, no installation shall be issued a construction permit unless the equipment and components of the approved system that will be installed have been MO/PETP tested and approved;

(IV) At the option of the owner/operator, full port ball valves may be installed just below the riser of the vapor chamber. The ball valves shall be sealed fully open at all times except during testing. The ball valve shall be tested in line during the dynamic back pressure blockage test;

(V) Detailed description of the storage tank(s). The storage tank(s) shall be—

(a) Type I tank(s). A Type I tank is an underground storage tank that shall be covered with not less than six inches (6") of soil and/or concrete; or

## 10 CSR 10-5.220

20 (b) Type II tank(s). A Type II tank is one that has any portion of the shell exposed to the atmosphere. A Type II tank shall be equipped with a vapor processor; and

(VI) Schedule of construction;

B. Obtain a construction permit prior to beginning construction. The director shall issue a construction permit or a permit rejection within thirty (30) days of receipt of the application. When an appeal is made following rejection of the application to construct, that appeal shall be filed within thirty (30) days of the notice of rejection;

C. Display the construction permit in a prominent location during construction;

D. Notify the department seven (7) calendar days prior to the anticipated completion date of underground piping and schedule a mutually acceptable inspection date. In the event that no mutually acceptable date is available, the staff director shall schedule the inspection date. The underground piping shall not be covered without visual inspection by the staff director. If defects are found, the staff director shall provide written notice of those defects;

E. Establish compliance with all rules and requirements of the department including those in Title 10 of

the Code of State Regulations ;

F. Document for the staff director that prior to the introduction of product, the tank and piping system were subjected to a construction pressurization test of not more than five pounds per square inch (5 psi) and not less than four and five-tenths pounds per square inch (4.5 psi) and maintained this pressure for not less than thirty (30) minutes;

G. Obtain staff director approval of final test methods and procedures that will be used to prove compliance;

H. Within thirty (30) days of completion of construction, conduct and pass final leak tests and dynamic back pressure/liquid blockage tests to show compliance with department requirements. The staff director may observe the

test; and

## 10 CSR 10-5.220

21 I. Obtain and maintain on-site in a prominent location the current operating permit from the director for the site and the specific vapor recovery system that was installed. The operating permit is renewable every five (5) years and shall be maintained according to subsection (3)(I) of this rule.

2. The director may approve experimental technology for a specific gasoline dispensing installation. Experimental technology may be approved for up to one (1) year for a limited number of stations under specific conditions determined by the staff director. Installations applying for approval of experimental technology shall—

A. Submit an application for director approval at least ninety (90) days prior to beginning construction. The application shall include, but not be limited to:

(I) Complete diagrams and a thorough description of the planned installation;

(II) Plumbing diagrams including vapor lines, vent lines, slope of return vapor lines, material of all underground, above ground and dispenser plumbing, grade of site in relation to tanks, plumbing, and dispensers; and

(III) Standards, test data, history, and related information for the proposed system;

B. Submit to the staff director a detailed plan for the construction and operation of the system. The plan shall include a description of the planned testing and record keeping for the installation. The director may issue the construction permit when all conditions of the testing installation are deemed satisfactory;

C. Display the construction permit in a prominent location during construction;

D. Install monitoring equipment to prove that the vapor recovery system is leak-tight if requested by the
staff director; and

E. Upon completion of testing, obtain and maintain on-site in a prominent location a current operating permit from the director for the specific innovative technology that is in operation. The permit shall specify the technology, the location and the time period the technology will be tested.

## 10 CSR 10-5.220

22 3. Existing installations that are subject to subsection (3)(E) or (3)(F) of this rule and undergo vapor recovery system modification shall—

A. Submit an application on a form supplied by the department for a permit to construct prior to beginning modifications. After the effective date of this rule, any revision to the department supplied forms will be presented to the regulated community for a forty-five (45)-day comment period. Applications for construction permits shall be submitted for projects that include, but are not limited to:

(I) Modifications that require breaking concrete in an area that may affect the vapor lines; and

(II) Modifications that may affect the vapor
lines themselves;

B. Supply any information required by the staff director for the specific installation. Such information may include, but not be limited to, plumbing diagrams, including vapor lines, vent lines, slope of vapor lines, material of all underground, above ground and dispenser plumbing, grade of site in relation to tanks, plumbing and dispensers, current CARB executive orders for the proposed system and equipment, and proof of compliance with all rules and requirements of the department including those in Title 10 of the Code of State Regulations ;

C. Obtain a construction permit prior to beginning the modification. Continued operation during the construction requires department approval. The director shall issue a construction permit or a permit rejection within thirty (30) days of receipt of the application. When an appeal is made following rejection of the application, that appeal shall be filed within thirty (30) days of the notice of rejection;

D. Display the construction permit in a prominent location during construction;

E. Establish a schedule for inspection and testing as required by the staff director and notify the department seven (7) calendar days prior to the anticipated completion date of underground piping and schedule a mutually acceptable inspection date. In the event that no mutually acceptable date is available, the staff director shall schedule

## 10 CSR 10-5.220

23 the inspection date. The underground piping shall not be covered without visual inspection by the staff director. If defects are found, the staff director shall provide written
notice of those defects;

F. Supply test results to the staff director;

G. Receive staff director approval of final test methods and procedures that will be used to prove compliance;

H. Within thirty (30) days of completion of construction, conduct and pass final leak tests and dynamic back pressure/liquid blockage tests to show compliance with department requirements. The staff director may observe the

tests; and

I. Upon completion of testing, obtain and display in a prominent location on-site the current operating permit from the director for the specific site and the specific vapor recovery system that was installed.

(I) The operating permit shall be maintained according to subsection (3)(I) of this rule, except paragraph (3)(I)2. of this rule shall not apply to initial fueling systems and ancillary refueling systems at automobile assembly installations.

(II) The operating permit is renewable every five (5) years, except for operating permits covering initial fueling systems and ancillary refueling systems at automobile assembly installations. Automobile assembly installations shall apply for an initial Stage II Operating Permit covering both their initial fueling systems and their ancillary refueling systems that will be current until their Part 70 Operating
Permit is renewed.

(III) Except for the initial Stage II Operating Permit, the operating permit for automobile assembly installations that covers their initial fueling systems and their ancillary refueling systems shall be incorporated as part of the installation applicable requirements of 10 CSR 10-6.065 Operating Permits.

(I) Operating Permits for Existing Installations. All existing installations subject to subsection (3)(E) or (3)(F) of this rule must apply to the director for an operating permit.

## 10 CSR 10-5.220

24 1. Initial operating permits. The term of the initial permit shall be established by the staff director. In order to obtain an operating permit an existing installation

shall—

A. Apply to the director for an operating permit within sixty (60) days of the date of the staff director’s notice to apply and test within ninety (90) days of the notice. However, no installation subject to this requirement shall operate after January 1, 1999, without an operating permit;

B. Provide documentation that the Stage II system is certified by CARB as having a vapor recovery or removal efficiency of at least ninety-five percent (95%);

C. Conduct and pass a department-approved back pressure blockage test and a department-approved leak decay test. The owner/operator of the installation shall schedule the tests and notify the staff director of the test dates at least seven (7) days prior to the testing date. The staff director may observe the tests. The owner/operator of the installation shall provide satisfactory test results to the staff director;

D. Designate a person(s) who has attended a department-approved training course for the Stage II equipment that is installed at that installation. A designated person shall be available for consultation to installation personnel and to the department;

E. Demonstrate that the installation maintains a system of record keeping that meets the staff director’s requirements; and

F. Establish compliance with all rules and requirements of the Missouri Department of Natural Resources including those in Title 10 of the Code of State Regulations

.

2. Renewal of operating permits. The operating permit is renewable on the date specified in the initial operating permit and for periods of five (5) years after the initial permit term expires. In order to renew the operating permit an installation shall—

## 10 CSR 10-5.220

25 A. Apply to the director for renewal of the operating permit and test within ninety (90) days prior to the

renewal date;

B. Demonstrate that the installation maintained all system components in good operating order during the preceding operating permit term including prompt efforts to establish compliance following “out-of-order” notices;

C. Schedule staff director-approved tests prior to the expiration date of the permit, notify the staff director of test dates at least fourteen (14) days prior to test dates and provide documentation that the system passed the tests;

D. Maintain records according to subsection (4)(F) of this rule;

E. An installation using a system that is decertified by CARB shall establish compliance with this rule within one (1) year or by the next renewal date of the operating permit whichever is longer. Failure to establish compliance will result in nonrenewal of the operating permit; and

F. After January 1, 2001, no operating permit shall be renewed without documentation that the Stage II system
in use at the installation can be demonstrated to achieve ninety-five percent (95%) efficiency as specified in paragraph (3)(E)1. of this rule. Replacement of equipment and/or components in place as part of an approved system on January 1, 1999, shall not be required as long as the equipment and/or components pass operating permit tests.

**(G) Construction Permits for Vapor Recovery Systems for New GDFs, Vapor Recovery System Modification for Existing GDFs,**  **and Stage I experimental technology.**

**1. Construction of a new GDF that requires a Stage I vapor recovery system, decommission of an existing Stage II**  **vapor recovery system, or major modification to an existing GDF. An owner or operator constructing a new GDF that requires a**  **Stage I vapor recovery system, decommissioning an existing Stage II vapor recovery system, or modifying an existing vapor**  **recovery system such that the fixed capital costs of the new components will exceed fifty percent (50%) of the fixed capital**  **cost of a new gasoline dispensing system (including only those components directly related to gasoline dispensing and storage)** 

**shall—**

## 10 CSR 10-5.220

26 **A. Submit an application on a form supplied by the department for a permit to construct at least thirty (30)**  **days prior to beginning construction. The application shall**
**include:**

**(I) Complete diagrams and a thorough description of the planned installation;** 

**(II) Plumbing diagrams including vent lines and material of all underground and aboveground plumbing;** 

**(III) For gasoline storage tanks subject to paragraph (3)(C)2. of this rule, current CARB Executive**  **Orders for the proposed Stage I vapor recovery system;**

**(IV) Detailed description of the storage tank(s); and** 

**(V) Schedule of construction;**

**B. Obtain a construction permit prior to beginning construction;** 

**C. Display the construction permit in a prominent location during construction;** 

**D. Establish compliance with all rules and requirements of Division 10 of Title 10**  **of the Code of State Regulations;** 

**E. Obtain staff director approval of final test methods and procedures that will be used to demonstrate**  **compliance;**

**F. Meet the testing requirements in subparagraph (3)(H)1.B. of this rule; and** 

**G. Obtain and maintain on-site in a prominent location the current operating permit from the director for the**  **site and the specific vapor recovery system that was installed. The operating permit shall be maintained according to subsection**  **(3)(H) of this rule.**

## 10 CSR 10-5.220

27 **2. Minor modification to existing GDF. An owner or operator of an existing GDF modifying an existing vapor**  **recovery system such that the fixed capital costs of the new components will not exceed fifty percent (50%) of the fixed**  **capital cost of a new gasoline dispensing system (including only those components directly related to gasoline dispensing and**  **storage) shall—**

**A. Submit a construction permit notification prior to construction for projects that include, but are not**  **limited to, any modification that—**

**(I) Requires breaking concrete in an area within fifteen (15) feet of the vapor lines or vent lines;** 

**(II) Modifies vapor lines or vent lines themselves;** 

**(III) Affects the operation of the vapor**
**recovery system; or**

**(IV) Could result in improper functioning of the vapor recovery system;** 

**B. Supply any information requested by the staff director for the specific installation. Such information**  **may include, but is not limited to, plumbing diagrams, including vapor or vent lines; material of all underground and aboveground**  **plumbing; current CARB executive orders for the proposed vapor recovery system and equipment; and proof of compliance with all**  **rules and requirements of Division 10 of Title 10 of the Code of State Regulations;** 

**C. Modify the vapor recovery system in accordance with the rules and requirements of Division 10 of**  **Title 10 of the Code of State Regulations. If after review of the application, or inspection of the modification to the vapor**  **recovery system, it is discovered that the modification is not in compliance with the rules and requirements of Division 10 of**  **Title 10 of the Code of State Regulations, the owner or operator will be subject to enforcement action, and must bring the**  **facility back into compliance with the rules and requirements of Division 10 of Title 10 of the Code of State Regulations;** 

**D. Meet the testing requirements in paragraph (3)(H)1. of this rule; and** 

## 10 CSR 10-5.220

28 **E. Upon completion of testing, obtain and display in a prominent location on-site the current operating**  **permit from the director for the specific site and the specific vapor recovery system that was installed. The operating permit**  **shall be maintained according to subsection (3)(H) of this rule.**

**3. Experimental Stage I technology. The director may approve Stage I experimental technology for a specific GDF.**  **Experimental technology may be approved for up to three (3) years for a limited number of GDFs under specific conditions**  **determined by the staff director. GDFs applying for approval of experimental technology shall—** 

**A. Submit an application for director approval at least ninety (90) days prior to beginning construction. The**  **application shall include, but not be limited to:**

**(I) Complete diagrams and a thorough description of the planned installation;** 

**(II) Plumbing diagrams including vent lines and material of all underground and aboveground plumbing;** 

**and**

**(III) Standards, test data, history, and related information for the proposed system;** 

**B. Submit to the staff director a detailed plan for the construction and operation of the system. The plan shall**  **include a description of the planned testing and record keeping for the GDF. The director may issue the construction permit when**  **all conditions of the testing GDF are deemed satisfactory;**

**C. Display the construction permit in a prominent location during construction;** 

**D. Install monitoring equipment to prove that the vapor recovery system is leak-tight if requested by the**  **staff director; and**

**E. Upon completion of testing, obtain and maintain on-site in a prominent location a current operating**  **permit from the director for the specific innovative technology that is in operation. The permit shall specify the technology,**  **the location, and the time period the technology will be tested.**

**4. Emergency Repairs.**

## 10 CSR 10-5.220

29 **A. Owners or operators of GDFs requiring emergency repair or replacement of vapor recovery system**  **components may immediately begin corrective construction if the construction is in response to an accident or event that—** 

**(I) Creates an abnormally high threat of fire;** 

**(II) Poses an environmental hazard by allowing release of liquid product onto the ground or abnormal**  **release of vapor into the air; and/or**

**(III) Threatens public safety; and**

**B. Owners or operators of GDFs electing to make emergency repair or replacement per subparagraph (3)(G)4.A. of**  **this rule shall contact the department within forty-eight (48) hours of the commencement of the repair or replacement to**  **determine what future action is required for compliance with**
**this rule.**

**5. Owners or operators of GDFs making minor modifications per subsection (3)(G)2. of this rule may begin**  **modification upon submittal of the construction permit**
**notification.**

**6. The director shall issue a construction permit or a permit rejection within thirty (30) days of receipt of all**  **construction permit applications submitted per paragraph (3)(G)1. of this rule.** 

**7. Owners or operators of GDFs shall pay the department a fee of one hundred dollars ($100) for each**  **construction permit application submitted in accordance with subsection (3)(G) of this rule.** 

**(H) Operating Permits. All owners or operators of installations subject to subsection (3)(C) or (3)(E) of this**  **rule shall apply to the director for an operating permit.**

**1. Completion of construction. To obtain an operating permit after the completion of construction, the owner**  **or operator of a GDF shall—**

**A. Apply to the director for an operating permit within thirty (30) days of construction completion;** 

## 10 CSR 10-5.220

30 **B. Conduct and pass a department-approved pressure decay test, pressure/vacuum valve test, and, where a**  **Stage II vapor recovery system is in place, a dynamic back pressure/liquid blockage test;** 

**C. Schedule the test and notify the staff director at least seven (7) days**  **prior to the test date. The staff director may observe the test, but it is not required that**  **the staff director be present and observe the test;**

**D. Provide the test results to the staff director;** 

**E. Demonstrate that the installation maintains a system of record keeping that meets the requirements of**  **subsection (4)(D) of this rule; and**

**F. Establish compliance with all rules and requirements of Division 10 of Title 10**  **of the Code of State Regulations.** 

**2. Renewal of operating permits. The operating permit is renewable on the date specified in the initial**  **operating permit and for periods of three (3) years after the initial permit term expires. In order to renew the operating**  **permit the owner or operator of a GDF shall—**

**A. Apply to the director for renewal of the operating permit and test within ninety (90) days prior to the**  **renewal date;**

**B. Demonstrate that the GDF maintained all vapor recovery system components in good operating order during**  **the preceding operating permit term including prompt efforts to establish compliance following “out-of-order” notices;** 

**C. Conduct and pass a department-approved pressure decay test, pressure/vacuum valve test, and, where a**  **Stage II vapor recovery system is in place, a dynamic back pressure/liquid blockage test, prior to the expiration date of**  **the permit;**

**D. Schedule the test and notify the staff director at least seven (7) days prior to the test date. The**  **staff director may observe the test, but it is not required that the staff director be present and observe the test;** 

## 10 CSR 10-5.220

31 **E. Provide the test results to the staff director; and** 

**F. Maintain records according to subsection (4)(D) of this rule.** 

**3. Owners or operators of an installation using a vapor recovery system that is decertified by CARB shall**  **establish compliance with this rule within one (1) year or by the next renewal date of the operating permit whichever is**  **longer. Failure to establish compliance will result in nonrenewal of the operating permit.** 

**4. Owners or operators of GDFs shall pay the department a fee of one hundred dollars ($100) for each**  **operating permit.**

( J **I** ) Owner/Operator Compliance. The owner or operator of a vapor recovery system subject to this rule shall—

1. Operate the vapor recovery system and the gasoline loading equipment in a manner that prevents—

A. Gauge pressure from exceeding four thousand five hundred (4,500) pascals (eighteen inches (18") of H 2 

## O) in the delivery vessel;

B. A reading equal to or greater than one hundred percent (100%) of the lower explosive limit (LEL), measured as propane at two point five (2.5) centimeters from all points on the perimeter of a potential leak source when measured by the method referenced in 10 CSR 10-6.030(14)(E) during loading or transfer operations; and

C. Visible liquid leaks during loading or transfer operations; and

2. Repair and retest within fifteen (15) days, a vapor recovery system that exceeds the limits in paragraph (3)( J **I** )1. of this rule; and

3. Reporting and record keeping shall be per subsection (4)( F **D** ) of this rule.

## 10 CSR 10-5.220

32 (K) Vapor Recovery Advisory Group. The St. Louis Vapor Recovery Advisory Group shall advise the staff director on vapor recovery issues in the St. Louis nonattainment area.

1. Composition. The advisory group will consist of one (1) representative from each of these agencies or organizations:

A. Missouri Department of Natural Resources, Air Pollution Control Program;

B. Missouri Department of Natural Resources, Hazardous Waste Program Underground Storage Tank Unit;

C. St. Louis City Air Pollution Control Agency or St. Louis County Air Pollution Control Agency;

D. Missouri Department of Agriculture, Division of Weights and Measures;

E. An organization representing petroleum

marketers;

F. An organization representing petroleum equipment contractors; and

G. An organization representing oil refiners.

2. Purpose. The St. Louis Vapor Recovery Advisory Group shall review, study and make recommendations to the staff director on vapor recovery issues. Any member of the advisory group may bring an issue to the attention of the group. The advisory group shall—

A. Review vapor recovery system components that frequently fail;

B. Review CARB certifications and decertifications of vapor recovery system components;

C. Develop modifications to established tests such as the leak decay test and the back pressure blockage test. Modified test procedures shall prove integrity of Stage I and Stage II systems but may be designed for cost and time efficiency; and

## 10 CSR 10-5.220

33 D. Review any other vapor recovery issues deemed appropriate by the staff director.

3. Limitations. The advisory group is subject to all applicable state and federal statutes and regulations. All advisory group meetings shall comply with the Missouri Sunshine Act. The advisory group assumes no regulatory authority.

(4) Reporting and Record Keeping.

(A) Owners and operators of petroleum storage tanks subject to subsection (3)(A) of this rule shall maintain written records of maintenance (both routine and unscheduled) performed on the tanks, all repairs made, the results of all tests performed and the type and quantity of petroleum liquid stored in them. Records shall be kept for two (2) years and made available to the staff director within five (5) business days of
a request.

(B) Owners or operators of **gasoline** loading installations subject to gasoline loading subsection (3)(B) of this rule shall keep complete records documenting the number of delivery vessels loaded and their owners. Records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request.

(C) The owner or operator of stationary storage tanks subject to gasoline transfer subsection (3)(C) of this rule shall keep records documenting the vessel owners and number of delivery vessels unloaded by each owner. Records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request. The owner or operator shall retain on-site copies of the loading ticket, manifest or delivery receipt for each grade of product received, subject to examination by the staff director upon request. If a delivery receipt is retained rather than a manifest or loading ticket, the delivery ticket shall bear the following information: vendor name, date of delivery, quantity of each grade, and the manifest or loading ticket number. The required retention on-site of the loading ticket, manifest or delivery receipt shall be limited to the four (4) most recent records for each grade of product.

( D **C** ) Owners or operators of gasoline delivery vessels subject to subsection (3)(D) of this rule shall keep records of all tests and maintenance performed on the vessels. Records shall be kept for two (2) years and made available to the staff

## 10 CSR 10-5.220

34 director within five (5) business days of a request. Also a copy of the vessel’s current Tank Truck Tightness Test results shall be kept with the delivery vessel at all times and made immediately available to the staff director upon request.

(E) Initial fueling and ancillary fueling of motor vehicles subject to subsection (3)(F) of this rule shall keep records on-site of all self-tests, self-inspections, defects found, repairs, and maintenance activities. Records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request.

( F **D** ) Owner/Operator Compliance. The owner or operator of a vapor recovery system subject to subsection (3)( J **C** ) **, (3)(E), or (3)(I)**  of this rule shall maintain records of department permits, inspection reports, enforcement documents, training certifications, gasoline deliveries, routine and unscheduled
maintenance
**,** and repairs and all results of tests conducted. Unless otherwise specified in this rule, records shall be kept for two (2) years and made available to the staff director within five (5) business days of a request.

(5) Test Methods.

(A) **Gasoline Loading.** Gasoline loading testing procedures to determine compliance with subparagraph (3)(B)2.A. of this rule shall be according to 10 CSR 10-6.030 subsection (14)(A) or by any method determined by the staff director. **The staff director, at any time, may monitor an installation subject to**  **subsection (3)(B) of this rule to confirm compliance with this**

**rule.**

(B) **Gasoline Delivery Vessels.** Gasoline delivery vessels testing and monitoring procedures to determine compliance with subsection (3)(D) of this rule and confirm the continuing existence of leak-tight conditions shall be according to 10 CSR 10-6.030 subsection (14)(B) or by any method determined by the
staff director **Testing procedures for gasoline delivery vessels to determine compliance with subsection (3)(D) of this rule**  **shall be according to 10 CSR 10-6.030 subsection (14)(B) or by any method determined by the staff director. The staff**  **director, at any time, may monitor a gasoline delivery vessel subject to subsection (3)(D) of this rule to confirm compliance** 
**with this rule**

.

(C) Fueling of Motor Vehicles **and Gasoline Transfer at**

**GDFs** . The staff director, at any time, may monitor a n

## 10 CSR 10-5.220

35 installation **GDF** subject to subsection **(3)(C) or** (3)(E) of this

rule **to confirm compliance with this rule** . The staff director may require a leak test, a back pressure blockage test, an air-toliquid test, a pressure/vacuum valve test or may require any test or monitoring procedure in order to determine compliance
with this rule.

(D) Delivery vessel, vapor recovery system or gasoline loading equipment may be monitored by the staff director at any time by a method determined by the staff director to confirm continuing compliance with this rule.

(E) An annual staff director-approved back pressure blockage test and/or air-to-liquid test may be required. Additional testing may also be required by the staff director in order to determine proper functioning of vapor recovery equipment.

(F) Installations containing initial fueling systems and ancillary refueling systems shall allow the department to make vapor recovery inspections at any time to ensure systems are in working order and are being maintained and operated according to permits and regulations, and manufacturer recommendations—

1. The department and local agency Stage II inspectors shall be allowed access in a timely manner. Department and local agency Stage II inspectors shall make every attempt to avoid disrupting assembly line production. This may be done by allowing initial fueling site personnel to make repairs on the spot, or within a reasonable time frame. However, this consideration will not affect recording of defects
or enforcement action; and

2. After repairs are made and notification by the plant is received, the department or local agency shall reinspect all defects found in official Stage II inspections. Failure by an installation to notify the department of repairs and request reinspection within fifteen (15) days of repair may
result in enforcement action.

( G **D** ) All emission controls that are approved by the director will not be considered federally enforceable

, and will
not shield a source from the federal obligation to comply with the underlying **federal** emission controls , by the EPA until submitted to EPA and approved by EPA in the state implementation plan.