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 ofplan 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 ofthe 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 oftechnical 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 ofExisting 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 ofNatural 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 the

word 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; coffee

shop; 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 serving

food; catering kitchen, commissary or similar place in which food or drink is placed for

sale 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 any

device, 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 processing

gases, 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 materials

resulting from spillage or other escape is prohibited. 

(C) Odor-bearing gases, vapors, fumes or

dusts arising from materials in process shall

be 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 storage 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 applicable

emission regulations, but whether the regulations and inspections would accomplish the

purpose of “enforcing compliance with applicable emission standards” which are federal

standards, 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 commission

has 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 to

require the installation of emission monitoring devices, but does have the authority to

require reports from sources of air pollution

relating 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 Storage, Loading and Transfer

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

JASON KANDER (10/31/14) CODE OF STATE REGULATIONS 7

Secretary of State
petroleum liquids in five specific areas:

petroleum storage tanks with a capacity

greater 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 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. 

PUBLISHER’S NOTE:  The secretary of state

has determined that the publication of the

entire 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 not

relieve 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 storage tanks. Subsection

(3)(A) of this rule shall not apply to

petroleum storage tanks that—

A. Store processed and/or treated

petroleum 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 seal

or 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 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. 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.

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 does

not 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 storage 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 storage 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 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 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 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 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 cm2 per meter

of tank diameter (1.0 in2 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 

8 CODE OF STATE REGULATIONS (10/31/14) JASON KANDER

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 an

absorber 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 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 loading 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

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 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 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 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 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 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. 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 storage tank system.

4. 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 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. 

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 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 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.

JASON KANDER (10/31/14) CODE OF STATE REGULATIONS 9

Secretary of State
4. 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 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;

(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-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 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) 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; and

2. 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 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 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.

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

10 CODE OF STATE REGULATIONS (10/31/14) JASON KANDER

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, 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

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 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; 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 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 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 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 departmentapproved 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; 

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.

(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—

JASON KANDER (10/31/14) CODE OF STATE REGULATIONS 11

Secretary of State
A. Gauge pressure from exceeding

four thousand five hundred (4,500) pascals

(eighteen inches (18") of H2O) 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)(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 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.

(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 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. 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 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, 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 approved

by the director will not be considered federally enforceable and will not shield a source

from 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. Rescinded

and 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) JASON KANDER

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 ofPetroleum 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 10-5.220, 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 network. 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 systems capture displaced vapors from vehicle fuel 

tanks during refueling and return the vapors to the underground storage tanks at the 

gasoline dispensing facility. The 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 canisters 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 began installing ORVR systems on new passenger vehicles in 

1998. Currently, more than 75% of gasoline 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 vehicle fleet for purposes of controlling motor 

vehicle refueling emissions. This federal rule allows states to remove Stage II programs 

from their SIP if certain 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 revisions to the Stage II regulations 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. Louis 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 prohibits revision of a SIP that would interfere with attainment 

of a NAAQS, reasonable further progress toward attainment of a NAAQS, or any other 

applicable requirement of the CAA. 

Furthermore, section 193 of the CAA prohibits 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 must 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 states that wish to remove Stage II 

requirements from their SIP titled Guidance on Removing Stage II Gasoline 

Vapor Control Programs from State 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 requirements, 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 incremental 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 impact on the area-wide 

VOC emissions inventory from the incremental emissions that result from the 

removal of Stage II vapor recovery systems. 

B. Input Parameters for the Equations in EPA’s Guidance Document. 

 The equations in the EPA guidance require appropriate area-specific values for 

the penetration of the ORVR in the motor vehicle fleet; in-use efficiencies of 

ORVR and Stage II systems; the proportion of gasoline dispensed by facilities 
3 

equipped with Stage II controls; the projected gasoline consumption for the area 

and time periods of interest; and the uncontrolled 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, QORVR. 

QORVR represents the proportion of annual 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 percentage of ORVR-equipped vehicles 

(Column 2), the percentage of vehicle miles traveled by ORVR-equipped 

vehicles (Column 3), and the percentage 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 comparing 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 Appendix 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 national fleet. The average age of tier 1 light-duty 

trucks (gross vehicle weight rating less than 6,000 pounds) is 1.1 years 

newer in St. Louis than the national fleet. The average age of tier 2 lightduty trucks (gross vehicle weight rating between 6,000 pounds and 8500 

pounds) is 1.4 years newer in St. Louis 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. Louis 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 distributions of the St. Louis fleet and the 

nationwide fleet, the percentage of gasoline dispensed into ORVRequipped vehicles for the national fleet presented in Table A-1 of the EPA 

guidance would be a conservative indicator of the percentage of gasoline 

dispensed into ORVR-equipped vehicles for the St. Louis fleet. 

2. In-use control efficiency of ORVR, ηORVR. 

ηORVR represents the in-use control efficiency 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, ηiuSII. 

ηiuSII represents the in-use control efficiency of Stage II vapor recovery 

systems when applied to vehicles that are not equipped with ORVR. 

Section 3.3.3 of the EPA guidance recommends using a value consistent 

with field test data and advises against relying on prior EPA guidance, 

new system certification efficiency, or state regulation claims regarding 

efficiency. Since Missouri’s inspection of Stage II-equipped installations 

does not include calculation of in-use efficiency, other test data must be 

used to establish the control efficiency. 

In May 2000, the San Diego Air Pollution 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 and used field tests and engineering 

calculations to estimate the in-use efficiency. Their report concluded that 

“American vacuum assist and balance vapor recovery systems averaged 

about 75% overall, with balance systems having the worst performance 

with efficiencies ranging from 63 to 68%.” All Stage II vapor recovery 

systems in St. Louis are of the balance type and their in-use control 

efficiency is assumed to be 65%, which 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, QSII. 

QSII 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 recommends 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 Missouri rule 10 CSR 10-5.220 Control of 

Petroleum Liquid Storage, Loading and Transfer sets 10,000 gallons per 

month as the applicability threshold for the Stage II vapor recovery 

requirements at gasoline dispensing facilities in the St. Louis area. 

Therefore, per section 3.3.3 of the EPA guidance, the recommended 

proportion of gasoline throughput dispensed 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 for the area and time periods of 

interest, GC. 

GC represents the projected ozone season gasoline consumption for the St. 

Louis area for the years analyzed in this demonstration. Section 3.5.1 of 

the EPA guidance suggests using the Federal Highway Administration 
5 

(FHA) to establish the baseline consumption for 2010 and then applying a 

nationwide growth factor derived from 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

Year (gallons)

GC, Ozone 

Season St. 

Louis Gasoline 

Consumption

1

 U.S. Department of Energy's National Annual Forecasts of gasoline 

consumption. Projected consumption of Motor Gasoline for 2010 

through 2020. 

http://www.eia.gov/oiaf/aeo/tablebrowser/#release=AEO2011&subject=

0-AEO2011&table=11-AEO2011®ion=0-0&cases=ref2011-

d020911a

2

 National Highway Administration. Total national gasoline consumption 

for April through October of 2010. 

http://www.fhwa.dot.gov/policyinformation/statistics/2010/33ga.cfm

3

 Gasoline consumption for St. Louis is 0.7764% of gasoline consumption 

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

Using the monthly nationwide gasoline consumption data for 2010 from 

the FHA report and adding the consumption for the months of April 

through October gives the 2010 nationwide gasoline consumption for 

Missouri’s ozone season. The DOE report was used to calculate an annual 

growth factor for the national gasoline consumption for 2011 through 

2020 by subtracting the previous year’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 nonattainment area accounts for 0.7764% of 

the nationwide gasoline consumption, which allows the St. Louis ozoneseason gasoline consumption to be separated from the nationwide gasoline 

consumption. 

6. Uncontrolled Displacement Refueling Emission Factor, EF. 

EF represents the uncontrolled displacement 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 requirements that are designed to reduce VOC 

emissions and RFG fuel is not required 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 square inch (psi) as shown in Table 

A-7 of the EPA guidance, which is reproduced 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. 

Td is the dispensed fuel temperature and 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. 

ΔT 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 the above parameters is presented in 

section 3.5.1 of the EPA guidance: 

EFሺgrams gallonሻ ൌ eሾିଵ.ଶ଻ଽ଼ି଴.଴଴ସଽሺ୼୘ሻା଴.଴ଶ଴ଷሺ୘ౚሻା଴.ଵଷଵହሺୖ୚୔ሻሿ ⁄

Using the above values for RVP, Td, and ΔT, 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 met by comparing the Stage II control 

efficiency to the ORVR control efficiency and demonstrating that the ORVR 

control program provides greater emission 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 two (2) emission reduction benefits: 

Deltai = (QSII)(ηiuSII) – (QSIIva)(CFi) – (QORVRi)(ηORVR)

Where: 

 Deltai is the comparison between the Stage II efficiency and the 

ORVR efficiency for year i; 

 QSII is the fraction of gasoline throughput covered by Stage II 

vapor recovery systems; 

 ηiuSII is the in-use Stage II control efficiency; 

 QSIIva is the fraction of gasoline throughput covered by traditional 

vacuum assist Stage II vapor recovery systems; 

 CFi 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; 

 QORVRi is the fraction of annual gallons of highway motor gasoline 

dispensed to ORVR-equipped vehicles for year i; and 

 ηORVR is the ORVR in-use efficiency. 

Since none of the Stage II systems in St. Louis are vacuum assist, QSIIva is zero 

and the product of QSIIva and CFi is zero. Therefore, the equation can be 

simplified to: 

Deltai = (QSII)(ηiuSII) – (QORVRi)(ηORVR) 

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: QSII ηiuSII QORVR ηORVR

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 reduction benefits than Stage II control 

systems. This additional emission reduction benefit for all future years satisfies 

the requirements of CAA section 193 for “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 emissions 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: 

Incrementi = (QSII)(1-QORVRi)(ηiuSII) – (QSIIva)(CFi) 

Where: 

 Incrementi is the incremental emission control for Stage II systems 

for year i; 

 QSII is the fraction of gasoline throughput covered by Stage II 

vapor recovery systems; 

 QORVRi is the fraction of annual gallons of highway motor gasoline 

dispensed to ORVR-equipped vehicles for year i; 

 ηiuSII is the in-use Stage II control efficiency; 

 QSIIva is the fraction of gasoline throughput covered by traditional 

vacuum assist Stage II vapor recovery systems; and 

 CFi 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 the St. Louis area are vacuum assist, QSIIva is 

zero (0) and the product of QSIIva and CFi is zero (0). Therefore, the equation can 

be simplified to: 

Incrementi = (QSII)(1-QORVRi)(ηiuSII) 

Table 3 shows the calculated Increment 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: QSII QORVR ηiuSII

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 incremental emission control for Stage II, the 

additional VOC emissions from the removal of Stage II may be calculated using 

the equation presented in section 3.5 of the EPA guidance: 

Tonsi = (Incrementi)(GCi)(EF) 

Where: 

 Tonsi is the overall effect of removing Stage II (tons) for year i; 

 Incrementi is the incremental emissions gain from removal of 

Stage II systems for year i; 

 GCi is the projected gasoline consumption (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 appropriate 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 the 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 result 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 temporary increases that are too small to 

interfere with attainment or progress toward attainment of a NAAQS. 

To demonstrate noninterference of these short-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 for 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% annual growth factor to the 2008 

vehicle miles traveled and source type 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 currently being studied by the Missouri 

Department of Natural Resources’ Air Quality Planning Section for various other 

SIP actions and the use of these years reduced the modeling resources required for 
11 

this demonstration. Version 2010b of MOVES is an update to version 2010a that 

increases the software’s functionality without significantly affecting the modeled 

emissions of criteria pollutants. EPA considers versions 2010a and 2010b to be 

the same model for SIP development purposes. Additional details regarding the 

development of the on-road mobile source VOC emissions inventories used in 

this demonstration can be found in Appendix G. 

The nonroad vehicle emissions were projected for the same years using the 

NONROAD2008a model and do not include the aircraft, commercial marine 

vessel, and railroad locomotive source categories. Additional details regarding 

the development of the nonroad mobile source 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 regulations 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 trucks starting in 2004, have generated substantial VOC 

reductions as the overall fleet turns over to these newer, cleaner vehicles. State 

measures include cleaner-burning reformulated 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 ൌ െ0.0457xଷ ൅ 276.41xଶ െ 557629x ൅ 374991576

where y is the predicted mobile source VOC emissions for year x. The values for 

the coefficients and constant are rounded 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 values) shows them to be randomly 

distributed with a sum that is close to zero, which indicates that a cubic regression 
12 

is appropriate for the data. The domain of the regression equation is [2008, 

2022], meaning the regression 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 = ‐0.0457x3 + 276.41x2 ‐ 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 emissions for all years of interest in this 

demonstration using the regression equation 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 practices, 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 source VOC emissions using the regression 

equation, the yearly decrease 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 for 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 emissions 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 progress of the St. Louis area toward attainment of 

the ozone NAAQS in two ways. 

First, the yearly decrease in VOC emissions from mobile sources is always 

greater than the short-term increase in VOC emissions due to removal of Stage II 

controls. This is evidenced in Table 7 by a comparison between 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 overall downward trend in future 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 railroad locomotive source categories. 

The timeframe in the SIP overlaps the timeframe 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, the 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 the 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 further evidence, beyond that presented in 

section III.D., that removal Stage II controls in the St. Louis area will not interfere 

with attainment or progress toward attainment 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 justify removal of Stage 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 greater 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 are satisfied for any year analyzed in the 

demonstration. 
16 

Section III.D. of this TSD shows the negligible impact of the small, short-term VOC 

emissions increases from Stage II removal on the overall progress of the St. Louis area 

toward attainment of the ozone NAAQS. All short-term emissions increases from the 

removal of Stage II requirements are smaller than the reductions in mobile source 

emissions for the years of interest in the demonstration. 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 are satisfied for any year analyzed in the 

demonstration. 

In conclusion, this Technical Support Document 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 using 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 air quality or violating the Clean Air Act 

prohibition on backsliding. The Stage II equipment 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 continue to work with the EPA, regulated 

industry, and other stakeholders to establish a reasonable phase-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

Average Age 8.1 8.1 7.8 7.5 9.8

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

Average Age 6.9 8.0 8.9 8.9 9.6
D-1 

APPENDIX D 
E-1 

APPENDIX E 
F-1 

APPENDIX F 
G-1 

APPENDIX G 

Stage II Removal Demonstration – Documentation of On-Road Mobile Source 

VOC Emissions Calculations in the St. Louis Ozone Nonattainment Area 

Section 1: St. Louis Nonattainment Area On-Road 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 (MOVES) 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 source 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 from 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 demonstration in order to provide a broad range of years demonstrating 

the continual decline of mobile source VOC emissions 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 was 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 same road type distribution 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 vehicle 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 data was also used to create the MOVES 

vehicle population input tables for 2008. Vehicle counts were converted from Mobile 6.2 

vehicle classes to MOVES source types using the source type fractions from 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 developed 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 input 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 other inputs to calculate 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 already took into account the reformulated gasoline 

used in the St. Louis nonattainment area. A separate input database 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 performed for 2008, 2015, 2017, and 2022, 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 road 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 been 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-3 

Section 2: Data Used to Develop the MOVES County Database Manager Inputs for the St. Louis Nonattainment Area fo2022 When using MOVES to calculate the on-road mobile source VOC emissions, default data was used in the county databaSpeed Distribution, Fuel Supply, Fuel Formulation, VMT Monthly Distribution, VMT Daily Distribution, and VMT Ho

for all five counties. Meteorology Data, Road Type Distribution, and Age Distribution Inputs are the same for 2008, 20

county database manager input tables developed by the Air Program for these four years, the data used to develop the in– 24 below. 2008 MOVES Inputs 

Table 1 – 2008 Source Type Population (MOVES Inputs for 2008 On-Road Mobile Source VOC Emissions) 

 Source Type Population by County 

YearID SourceTypeName SourceTypeID Franklin Jefferson St Charles St Louis County 

2008 Motorcycle 11 6,067 13,018 11,151 19,242008 Passenger Car 21 46,568 98,009 144,441 527,142008 Passenger Truck 31 45,890.24 82,509.19 110,385.78 303,295.72008 Light Commercial Truck 32 16,768.76 28,420.81 35,913.22 97,845.22008 Refuse Truck 41 8.25 41 35.5 93.2008 

Single Unit Short-haul Truck 42 24.75 123 106.5 280.

2008 

Single Unit Long-haul Truck 43 302.08 541.2 549.04 2,709.2

2008 Motor Home 51 21.53 19.34 19.44 50.12008 School Bus 52 813.93 900.99 1,019.79 3,623.52008 Transit Bus 53 61.05 66.99 76.07 270.22008 Intercity Bus 54 44.26 71.09 82.23 378.62008 

Combination Short-haul Truck 61 370.31 324.37 327.86 791.1

2008 

Combination Long-haul Truck 62 306.84 257.02 257.57 544.9
G-4 

Table 2 – 2008 Annual VMT by HPMS Vehicle Type, County, and Year (MOVES Inputs for 2008 On-Road Mobile So

 HPMSBaseYearVMT by County 

HPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St. Louis 

10 Motorcycles 2008 11,619,323 13,841,651 20,770,584 91,989,970 20 Passenger Cars 2008 707,169,172 811,173,607 1,171,243,667 5,115,865,231 30 

Other 2 axle-4 tire vehicles 2008 799,130,600 924,394,839 1,342,595,411 5,875,722,138 

40 Buses 2008 4,781,820 5,578,789 8,183,119 35,928,481 50 Single Unit Trucks 2008 29,351,955 33,386,793 47,634,481 207,228,073 60 Combination Trucks 2008 84,673,330 96,333,716 137,528,782 598,448,609 
G-5 

Table 3 – 2008 Inspection and Maintenance Data (MOVES Inputs for 2008 On-Road Mobile Source VOC Emissions) Pol Process ID 

State ID 

Year ID 

Source Type ID 

Fuel Type ID 

IM Program ID 

Inspect Freq 

Test Standards ID 

Beg Model Year ID 

End Model Year ID 

Use IM Y/N 

Compliae Factor 

101 29 2008 21 1 1 1 11 1971 1995 N 93101 29 2008 21 1 10 2 51 1996 2006 Y 97101 29 2008 31 1 1 1 11 1971 1995 N 93101 29 2008 31 1 10 2 51 1996 2006 Y 92101 29 2008 32 1 1 1 11 1971 1995 N 93101 29 2008 32 1 10 2 51 1996 2006 Y 86102 29 2008 21 1 1 1 11 1971 1995 N 93102 29 2008 21 1 10 2 51 1996 2006 Y 97102 29 2008 31 1 1 1 11 1971 1995 N 93102 29 2008 31 1 10 2 51 1996 2006 Y 92102 29 2008 32 1 1 1 11 1971 1995 N 93102 29 2008 32 1 10 2 51 1996 2006 Y 86112 29 2008 21 1 7 1 41 1971 1995 N 93112 29 2008 21 1 8 2 43 1996 2006 Y 97112 29 2008 31 1 7 1 41 1971 1995 N 93112 29 2008 31 1 8 2 43 1996 2006 Y 92112 29 2008 32 1 7 1 41 1971 1995 N 93112 29 2008 32 1 8 2 43 1996 2006 Y 86113 29 2008 21 1 7 1 41 1971 1995 N 93113 29 2008 21 1 8 2 43 1996 2006 Y 97113 29 2008 31 1 7 1 41 1971 1995 N 93113 29 2008 31 1 8 2 43 1996 2006 Y 92113 29 2008 32 1 7 1 41 1971 1995 N 93113 29 2008 32 1 8 2 43 1996 2006 Y 86
G-6 

2015 MOVES Inputs Table 4 – 2015 Source Type Population (MOVES Inputs for 2015 On-Road Mobile Source VOC Emissions) 

 Source Type Population by County 

YearID SourceTypeName SourceTypeID Franklin Jefferson St Charles 

St Louis County 

2015 Motorcycle 11 6,733 14,448 12,376 21,357 2015 Passenger Car 21 51,683 108,775 160,307 585,053 2015 Passenger Truck 31 50,931 91,572 122,511 336,611 2015 Light Commercial Truck 32 18,611 31,543 39,858 108,593 2015 Refuse Truck 41 9 46 39 104 2015 

Single Unit Short-haul Truck 42 28 137 118 311 

2015 

Single Unit Long-haul Truck 43 335 601 609 3,007 

2015 Motor Home 51 24 21 22 56 2015 School Bus 52 903 1,000 1,132 4,022 2015 Transit Bus 53 68 74 84 300 2015 Intercity Bus 54 49 79 91 420 2015 

Combination Short-haul Truck 61 411 360 364 878 

2015 

Combination Long-haul Truck 62 341 285 286 605 
G-7 

Table 5 – 2015 Annual VMT by HPMS Vehicle Type, County, and Year (MOVES Inputs for 2015 On-Road Mobile So

 HPMSBaseYearVMT by County 

HPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St. Louis 

10 Motorcycles 2015 12,895,647 15,362,086 23,052,127 102,094,6020 Passenger Cars 2015 784,848,108 900,276,901 1,299,898,826 5,677,817,0030 

Other 2 axle-4 tire vehicles 2015 886,911,031 1,025,934,909 1,490,072,687 6,521,140,32

40 Buses 2015 5,307,079 6,191,590 9,081,993 39,875,0450 Single Unit Trucks 2015 32,576,118 37,054,162 52,866,886 229,991,0260 Combination Trucks 2015 93,974,265 106,915,484 152,635,619 664,185,14
G-8 

Table 6 – 2015 Inspection and Maintenance Data (MOVES Inputs for 2015 On-Road Mobile Source VOC Emissions) Pol Process ID 

State ID 

Year ID 

Source Type ID 

Fuel Type ID 

IM Program ID 

Inspect Freq 

Test Standards ID 

Beg Model Year ID 

End Model Year ID 

Use IM Y/N 

Compliae Factor 

101 29 2015 21 1 1 1 11 1971 1995 N 93101 29 2015 21 1 10 2 51 1996 2013 Y 97101 29 2015 31 1 1 1 11 1971 1995 N 93101 29 2015 31 1 10 2 51 1996 2013 Y 92101 29 2015 32 1 1 1 11 1971 1995 N 93101 29 2015 32 1 10 2 51 1996 2013 Y 86102 29 2015 21 1 1 1 11 1971 1995 N 93102 29 2015 21 1 10 2 51 1996 2013 Y 97102 29 2015 31 1 1 1 11 1971 1995 N 93102 29 2015 31 1 10 2 51 1996 2013 Y 92102 29 2015 32 1 1 1 11 1971 1995 N 93102 29 2015 32 1 10 2 51 1996 2013 Y 86112 29 2015 21 1 7 1 41 1971 1995 N 93112 29 2015 21 1 8 2 43 1996 2013 Y 97112 29 2015 31 1 7 1 41 1971 1995 N 93112 29 2015 31 1 8 2 43 1996 2013 Y 92112 29 2015 32 1 7 1 41 1971 1995 N 93112 29 2015 32 1 8 2 43 1996 2013 Y 86113 29 2015 21 1 7 1 41 1971 1995 N 93113 29 2015 21 1 8 2 43 1996 2013 Y 97113 29 2015 31 1 7 1 41 1971 1995 N 93113 29 2015 31 1 8 2 43 1996 2013 Y 92113 29 2015 32 1 7 1 41 1971 1995 N 93113 29 2015 32 1 8 2 43 1996 2013 Y 86
G-9 

2017 MOVES Inputs Table 7 – 2017 Source Type Population (MOVES Inputs for 2017 On-Road Mobile Source VOC Emissions) 

 Source Type Population by County 

YearID SourceTypeName SourceTypeID Franklin Jefferson St Charles St Louis County 

2017 Motorcycle 11 6,937 14,885 12,750 22,002017 Passenger Car 21 53,245 112,063 165,152 602,732017 Passenger Truck 31 52,470 94,340 126,214 346,782017 Light Commercial Truck 32 19,174 32,496 41,063 111,872017 Refuse Truck 41 9 47 41 102017 

Single Unit Short-haul Truck 42 29 141 122 32

2017 

Single Unit Long-haul Truck 43 345 619 628 3,09

2017 Motor Home 51 25 22 22 52017 School Bus 52 931 1,030 1,166 4,142017 Transit Bus 53 70 77 87 302017 Intercity Bus 54 50 81 94 432017 

Combination Short-haul Truck 61 423 371 375 90

2017 

Combination Long-haul Truck 62 351 294 295 62
G-10 

Table 8 – 2017 Annual VMT by HPMS Vehicle Type, County, and Year (MOVES Inputs for 2017 On-Road Mobile So

 HPMSBaseYearVMT by County 

HPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St. Louis 

10 Motorcycles 2017 13285,417 15,826,405 23,748,877 105,180,4120 Passenger Cars 2017 808,570,142 927,487,770 1,339,188,268 5,849,429,0230 

Other 2 axle-4 tire vehicles 2017 913,717,917 1,056,943,792 1,535,110,134 6,718,241,79

40 Buses 2017 5,467,485 6,378,731 9,356,496 41,080,2650 Single Unit Trucks 2017 33,560,731 38,174,124 54,464,788 236,942,5060 Combination Trucks 2017 96,814,637 110,147,005 157,249,031 684,260,14
G-11 

Table 9 – 2017 Inspection and Maintenance Data (MOVES Inputs for 2017 On-Road Mobile Source VOC Emissions) Pol Process ID 

State ID 

Year ID 

Source Type ID 

Fuel Type ID 

IM Program ID 

Inspect Freq 

Test Standards ID 

Beg Model Year ID 

End Model Year ID 

Use IM Y/N 

Compliae Factor 

101 29 2017 21 1 1 1 11 1971 1995 N 93101 29 2017 21 1 10 2 51 1996 2015 Y 97101 29 2017 31 1 1 1 11 1971 1995 N 93101 29 2017 31 1 10 2 51 1996 2015 Y 92101 29 2017 32 1 1 1 11 1971 1995 N 93101 29 2017 32 1 10 2 51 1996 2015 Y 86102 29 2017 21 1 1 1 11 1971 1995 N 93102 29 2017 21 1 10 2 51 1996 2015 Y 97102 29 2017 31 1 1 1 11 1971 1995 N 93102 29 2017 31 1 10 2 51 1996 2015 Y 92102 29 2017 32 1 1 1 11 1971 1995 N 93102 29 2017 32 1 10 2 51 1996 2015 Y 86112 29 2017 21 1 7 1 41 1971 1995 N 93112 29 2017 21 1 8 2 43 1996 2015 Y 97112 29 2017 31 1 7 1 41 1971 1995 N 93112 29 2017 31 1 8 2 43 1996 2015 Y 92112 29 2017 32 1 7 1 41 1971 1995 N 93112 29 2017 32 1 8 2 43 1996 2015 Y 86113 29 2017 21 1 7 1 41 1971 1995 N 93113 29 2017 21 1 8 2 43 1996 2015 Y 97113 29 2017 31 1 7 1 41 1971 1995 N 93113 29 2017 31 1 8 2 43 1996 2015 Y 92113 29 2017 32 1 7 1 41 1971 1995 N 93113 29 2017 32 1 8 2 43 1996 2015 Y 86
G-12 

2022 MOVES Inputs Table 10 – 2022 Source Type Population (MOVES Inputs for 2022 On-Road Mobile Source VOC Emissions) 

 Source Type Population by County 

Year ID Source Type Name 

Source Type ID Franklin Jefferson St Charles St Louis County 

2022 Motorcycle 11 7,473 16,035 13,735 23,703 2022 Passenger Car 21 57,360 120,723 177,916 649,318 2022 Passenger Truck 31 56,525 101,631 135,968 373,586 2022 Light Commercial Truck 32 20,655 35,007 44,236 120,521 2022 Refuse Truck 41 10 51 44 115 2022 

Single Unit Short-haul Truck 42 31 152 131 346 

2022 

Single Unit Long-haul Truck 43 372 667 676 3,337 

2022 Motor Home 51 27 24 24 62 2022 School Bus 52 1,003 1,110 1,256 4,463 2022 Transit Bus 53 75 83 94 333 2022 Intercity Bus 54 54 88 101 466 2022 

Combination Short-haul Truck 61 456 400 404 975 

2022 

Combination Long-haul Truck 62 378 317 317 671 
G-13 

Table 11 – 2022 Annual VMT by HPMS Vehicle Type, County, and Year (MOVES Inputs for 2022 On-Road Mobile S

 HPMS Base Year VMT by County 

HPMS Vtype ID HPMS Vtype Name 

Year ID Franklin Jefferson St. Charles 

St. Louis County 

10 Motorcycles 2022 14,312,168 17,049,533 25,584,286 113,309,1720 Passenger Cars 2022 871,059,680 999,167,739 1,442,686,099 6,301,496,3130 

Other 2 axle-4 tire vehicles 2022 984,333,696 1,138,628,640 1,653,749,592 7,237,454,41

40 Buses 2022 5,890,034 6,871,705 10,079,604 44,255,1150 Single Unit Trucks 2022 36,154,439 41,124,373 58,674,045 255,254,3660 Combination Trucks 2022 104,296,860 118,659,606 169,401,866 737,142,50
G-14 

Table 12 – 2022 Inspection and Maintenance Data (MOVES Inputs for 2022 On-Road Mobile Source VOC Emissions) Pol Process ID 

State ID 

Year ID 

Source Type ID 

Fuel Type ID 

IM Program ID 

Inspect Freq 

Test Standards ID 

Beg Model Year ID 

End Model Year ID 

Use IM Y/N 

Compliae Factor 

101 29 2022 21 1 1 1 11 1971 1995 N 93101 29 2022 21 1 10 2 51 1996 2020 Y 97101 29 2022 31 1 1 1 11 1971 1995 N 93101 29 2022 31 1 10 2 51 1996 2020 Y 92101 29 2022 32 1 1 1 11 1971 1995 N 93101 29 2022 32 1 10 2 51 1996 2020 Y 86102 29 2022 21 1 1 1 11 1971 1995 N 93102 29 2022 21 1 10 2 51 1996 2020 Y 97102 29 2022 31 1 1 1 11 1971 1995 N 93102 29 2022 31 1 10 2 51 1996 2020 Y 92102 29 2022 32 1 1 1 11 1971 1995 N 93102 29 2022 32 1 10 2 51 1996 2020 Y 86112 29 2022 21 1 7 1 41 1971 1995 N 93112 29 2022 21 1 8 2 43 1996 2020 Y 97112 29 2022 31 1 7 1 41 1971 1995 N 93112 29 2022 31 1 8 2 43 1996 2020 Y 92112 29 2022 32 1 7 1 41 1971 1995 N 93112 29 2022 32 1 8 2 43 1996 2020 Y 86113 29 2022 21 1 7 1 41 1971 1995 N 93113 29 2022 21 1 8 2 43 1996 2020 Y 97113 29 2022 31 1 7 1 41 1971 1995 N 93113 29 2022 31 1 8 2 43 1996 2020 Y 92113 29 2022 32 1 7 1 41 1971 1995 N 93113 29 2022 32 1 8 2 43 1996 2020 Y 86
G-15 

MOVES Inputs Used for 2008, 2015, 2017, and 2022 

Table 13 – Road Type Distribution (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 0.001472
G-16 

Table 14 –Vehicle Age Distribution (MOVES Inputs for 2008, 2015, 2017, and 2022 On-Road Mobile Source V Source Type ID Age ID 11 21 31 32 41 42 43 51 52 53 

0 0.019 0.0248 0.016038 0.015215 0.006 0.006 0.03372 0.019407 0.022549 0.022677 0.1 0.0646 0.0564 0.059034 0.058508 0.0045 0.0045 0.054157 0.048521 0.039325 0.03937 0.2 0.1035 0.0666 0.063189 0.062229 0.0132 0.0132 0.092687 0.158149 0.129508 0.130555 0.3 0.1096 0.0649 0.073971 0.073529 0.0144 0.0144 0.057163 0.057986 0.082002 0.084645 0.4 0.1172 0.0653 0.081725 0.079405 0.0138 0.0138 0.098055 0.068814 0.07432 0.076743 05 0.0874 0.0632 0.072225 0.07206 0.0291 0.0291 0.05743 0.075516 0.060754 0.062113 06 0.0922 0.0633 0.075227 0.075017 0.0378 0.0378 0.060728 0.071294 0.059753 0.061551 0.7 0.0713 0.0679 0.075731 0.074101 0.0258 0.0258 0.034794 0.048222 0.045101 0.04668 0.8 0.061 0.0675 0.069095 0.069315 0.0249 0.0249 0.049567 0.050551 0.053801 0.053336 09 0.0435 0.0652 0.059343 0.060606 0.039 0.039 0.065329 0.101607 0.075238 0.074281 0.

10 0.036 0.0604 0.056546 0.058019 0.0351 0.0351 0.065952 0.060365 0.052757 0.052173 011 0.0255 0.0501 0.045379 0.044021 0.0309 0.0309 0.066337 0.035034 0.038694 0.038608 0.12 0.0208 0.0488 0.040069 0.041299 0.0351 0.0351 0.042714 0.030037 0.038252 0.038379 0.13 0.0189 0.039 0.031719 0.032547 0.083 0.083 0.048635 0.022609 0.033622 0.033505 0.14 0.0171 0.042 0.029341 0.030746 0.0836 0.0836 0.033323 0.026945 0.032499 0.031744 0.15 0.0122 0.0313 0.025132 0.025766 0.0492 0.0492 0.018302 0.014853 0.01522 0.015277 0.16 0.0119 0.0274 0.020261 0.020238 0.0441 0.0441 0.01489 0.014543 0.016624 0.016485 0.17 0.0073 0.0213 0.01591 0.015912 0.0267 0.0267 0.010657 0.011093 0.012019 0.01218 0.18 0.0063 0.0184 0.014002 0.013972 0.0399 0.0399 0.009968 0.011696 0.014667 0.014636 0.19 0.0063 0.0138 0.011117 0.011398 0.0609 0.0609 0.012691 0.012448 0.018417 0.017168 0.20 0.0064 0.0121 0.014109 0.014268 0.0333 0.0333 0.018084 0.014903 0.019136 0.018141 0.21 0.0054 0.0083 0.015761 0.015219 0.0558 0.0558 0.00363 0.01022 0.014831 0.014247 0.22 0.0068 0.0065 0.011686 0.011205 0.054 0.054 0.00501 0.010636 0.017272 0.016478 0.23 0.0097 0.0049 0.00791 0.008124 0.0351 0.0351 0.003627 0.006385 0.007661 0.00744 024 0.013837 0.003694 0.00582 0.006825 0.022815 0.022815 0.003017 0.003218 0.003631 0.003569 0.25 0.019738 0.002785 0.004029 0.004856 0.01483 0.01483 0.002668 0.001864 0.001955 0.001889 0.26 0.006525 0.002099 0.002201 0.002308 0.009639 0.009639 0.002379 0.001137 0.001109 0.001082 0.27 0 0.001582 0.001069 0.001073 0.006266 0.006266 0.00214 0.00071 0.000645 0.000647 0.28 0 0.00044 0.000253 0.000245 0.004073 0.004073 0.001953 0.000417 0.000378 0.000362 0.29 0 0 0.000147 0.000139 0.002647 0.002647 0.001784 0.00024 0.000223 0.000197 0.30 0 0 0.001957 0.001836 0.064531 0.064531 0.028609 0.010581 0.018036 0.013841 0.
G-17 

Table 15 – Average Monthly Temperatures by Hour of the Day for Franklin County in Fahrenheit (MOVES Inpu2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 25.8 29 39.1 48.4 55.9 68.2 70.9 67.1 60.6 49 2 24.8 27.4 37 46.4 54.7 67.1 69.6 66.2 60.8 47.9 3 23.8 26.3 35.8 45 53.6 66 68.8 65.4 60 47.1 4 22.8 25.3 34.5 44.1 52.6 65 68.1 64.8 59.1 46.5 5 22 24.9 33.5 43.2 51.7 64.1 67.5 63.9 58.6 45.7 6 21.4 24.2 32.6 42.7 51.1 63.5 66.8 63.4 58.2 45.1 7 21.2 23.8 32.1 42.7 52.6 65.7 68.2 63.9 57.9 44.6 8 21 23.4 32.4 45.3 56.2 69.3 71.4 67.6 60 45.9 9 22.2 24.9 36.4 48.9 59.6 72.9 75.2 71.7 63.8 50.9 

10 26.6 27.8 40.5 52.5 63.2 76.2 78.5 75.7 67.8 56 11 31.2 31.1 44.7 55.7 66.4 79 81.3 78.9 71.4 60.5 12 36 34.3 48.5 58.5 68.8 81.3 83.6 81.2 74.4 63.9 13 39.6 37.2 51.7 61.5 70.6 83 85.6 82.9 76.5 66.1 14 42.4 39.5 53.9 63.3 72.1 84.3 87 84.1 77.9 67.5 15 44 41 55.6 64.9 73.6 85.1 88 84.9 78.7 68.4 16 44.4 41.6 56.3 65.8 74.3 85.5 88.1 85.1 78.7 68.5 17 43.2 41.4 56.1 65.6 74.3 85.2 87.7 84.7 77.9 67.4 18 39.4 39.9 54.8 64.6 73.3 84.1 86.7 83.3 75.8 64.2 19 35.2 37 51.7 62.1 71.3 82.3 84.6 80.4 71.3 58.9 20 32.8 34.9 47.9 58.2 67.3 79 81 75.9 67 55.9 21 31 33.6 45.7 55.6 63.2 74.6 76.9 72.5 65.1 54.1 22 29.6 32.2 43.9 53.4 60.7 72.2 75 70.6 63.8 52.7 23 28.2 30.9 42.3 51.5 58.9 70.7 73.4 69.2 62.5 51.3 24 27.2 29.9 40.5 50 57.2 69.3 72.1 68.1 61.4 50.2 
G-18 

Table 16 – Average Monthly Percent Relative Humidity by Hour of the Day for Franklin County (MOVES Input

2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 68.3 76 71.8 70.6 77 78.3 83.9 86.1 88.2 77 2 69 77.2 72.8 72.9 77.2 80.2 84.4 86.9 88.5 78.7 3 70.1 78 73.9 74.5 78.2 81.6 85.3 87.5 89.2 79.8 4 70.9 78.3 75.3 75.3 79.3 82.4 86.1 88.1 90.1 80.4 5 71.8 78.3 76.8 76.1 80.5 83.8 86.4 89.3 90.4 81.6 6 72.3 78.9 77.6 77 81.1 84.4 87.3 89.6 90.4 82.5 7 72 78.8 78.2 77.6 80.3 83 85.8 89 90.4 83.4 8 72 78.8 78.3 74.5 76.2 77.9 81.4 84.9 89.5 83.2 9 71.2 77.6 74.8 69.8 71.5 72.4 74.9 77.5 84.7 76.8 

10 66.9 74.3 69.7 64.8 65.8 66.9 69.3 70.2 77.2 67.7 11 62 70.4 63.5 61.1 61.1 62.1 64.5 64.2 70.5 59.4 12 56.8 67 58.7 58.2 58.1 58.2 60.9 60 64.6 53.3 13 53 63.8 54.8 55 56.3 55.4 57.9 57.2 60.9 49.9 14 50.2 61.5 52.6 53 55.1 53.7 55.8 55.4 58.3 47.7 15 48.4 60 51 51.1 53.1 52.2 54.6 54.2 56.8 46.3 16 47.3 59.4 50.7 49.7 52.5 51.5 54.4 54 56.6 46 17 47.9 59.8 50.7 49.1 51.7 51.5 55.1 54.9 58.1 47.2 18 51.2 61.6 52.5 49.9 52.1 52.8 56.7 57.6 62.8 52.3 19 55.5 65.4 56.2 52.8 54.6 55.5 61.1 63.5 72.5 61.5 20 58.3 68.2 61 57.5 60.3 61.6 68.4 72.7 80.5 66.9 21 60.6 70.1 63.9 60.8 66.3 68.8 75.3 78.4 83.9 69.6 22 62.8 72 66.3 63.9 70.3 72.8 78.3 81.9 85.3 71.9 23 64.5 73.7 68.2 66.4 73.1 75 80.7 83.8 86.4 73.7 24 66.1 75.1 70.3 68.3 75.4 77 82.3 85.2 87.6 75.6 
G-19 

Table 17 – Average Monthly Temperatures by Hour of the Day for Jefferson County in Fahrenheit (MOVES Inp2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 25.6 28.3 38.5 47.4 55 68.3 70.1 67 60.2 48.6 2 24.7 26.8 36.3 45.5 53.8 67.3 68.8 66.1 60.4 47.7 3 23.7 25.7 35.2 44.3 52.8 66.3 68.1 65.3 59.5 46.9 4 22.5 24.8 34.2 43.3 51.8 65.2 67.5 64.6 58.9 46.3 5 22 24.2 33.3 42.6 50.9 64.5 66.8 63.9 58.2 45.4 6 21.2 23.5 32.3 42.3 50.5 63.8 66.2 63.4 57.9 44.8 7 20.8 23.1 31.8 42.3 52.1 66 67.6 63.9 57.6 44.3 8 20.8 22.9 32 44.9 55.7 69.6 70.8 67.6 59.9 45.6 9 22 24.2 35.7 48.4 58.9 73 74.5 71.6 63.7 50.7 

10 26.2 27 39.5 51.7 62.4 76.3 77.6 75.6 67.6 55.8 11 30.7 30 43.6 54.7 65.5 78.9 80.3 78.7 71.3 60.2 12 35 33.2 47.1 57.1 67.7 81.1 82.5 80.8 74.2 63.7 13 38.3 35.7 50.1 59.7 69.3 82.8 84.3 82.5 76.4 65.8 14 41.2 37.9 52.3 61.6 70.4 83.9 85.6 83.7 77.7 67.2 15 42.9 39.2 53.7 62.9 71.7 84.6 86.6 84.4 78.5 68.1 16 43.3 40 54.5 63.8 72.6 84.9 86.9 84.4 78.6 68.1 17 42.1 39.8 54.3 63.5 72.6 84.6 86.5 84.2 77.8 67.1 18 38.5 38.3 53 62.6 71.6 83.6 85.4 82.7 75.6 63.9 19 34.4 35.7 50 60.1 69.7 81.8 83.4 79.9 71 58.7 20 32 33.6 46.8 56.8 65.8 78.6 79.9 75.6 66.7 55.6 21 30.3 32.1 44.6 54.1 62 74.4 76.1 72.3 64.7 53.7 22 29.1 31.2 42.7 52.2 59.7 72.2 74.1 70.4 63.3 52.3 23 28 29.9 41.4 50.3 57.6 70.7 72.6 69 62.1 50.9 24 27 29.1 39.7 48.9 56.2 69.4 71.3 68.1 61.1 49.7 
G-20 

Table 18 – Average Monthly Percent Relative Humidity by Hour of the Day for Jefferson County (MOVES Inpu

2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 67.9 75.6 72.4 70.8 76.6 76.7 83 85.5 87.6 77.2 2 69 77.1 73 73.1 76.8 78.3 83.8 86.6 87.6 78.3 3 70.1 78 74.1 74.4 77.6 79.9 84.6 86.9 88.5 80.1 4 71.2 78.2 75.2 75.5 78.7 81.2 85.2 87.8 88.8 80.7 5 71.8 78.2 76.1 76.1 79.5 82.3 85.8 88.4 89.4 81.9 6 72.3 78.8 77.6 76.9 80.1 83.2 86.3 88.7 89.4 82.8 7 72.6 78.8 78.2 77.3 79.3 81.3 85.2 88.4 89.4 83.4 8 72.3 78.4 78.5 73.9 75 76 80.5 84 88.2 83.2 9 71.1 77.2 75.4 69 70.7 70.4 73.8 76.7 83.2 77.1 

10 67.1 74.2 70.2 64.4 65 64.8 68.5 69.4 76.1 67.5 11 62.2 70.5 64.4 60.9 60.3 60.1 63.7 63.8 69.5 58.9 12 57.2 67.1 59.9 58.5 57.6 56.1 60 59.5 63.9 52.9 13 53.7 64.7 56.4 55.6 56.1 53 57.4 56.9 60 49.3 14 50.9 62.1 54.1 53.4 54.8 51.8 55 55.1 57.9 46.8 15 48.8 60.8 53 51.6 53.4 50.2 53.7 54.1 56.4 45.5 16 47.7 59.9 52.5 50.1 52.4 49.5 53.5 54.1 56 45.4 17 48.1 60.1 52.7 49.7 52 49.5 53.9 54.8 57.5 46.4 18 51.3 61.6 54.4 50.7 52.1 50.5 55.6 57.6 62.3 51.7 19 55.6 65.2 58.2 54 54.5 53.5 59.7 63.5 71.7 61 20 58.2 68.3 62.5 58.4 60.3 59.2 67.1 71.6 79.3 66.7 21 60.5 70.2 65.3 61.8 66.2 66.5 73.7 77.6 82.9 69.6 22 62.5 71.9 67.5 64.5 70 70.6 77.2 81 84.6 71.8 23 64.2 73.6 69.5 67.3 73.2 72.7 79.5 83.2 85.8 73.7 24 65.8 74.7 71.3 68.7 75.3 74.9 81.1 84.3 86.7 75.8 
G-21 

Table 19 – Average Monthly Temperatures by Hour of the Day for St. Charles County in Fahrenheit (MOVES In2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 24.3 26.9 37.9 47.5 54.9 68.8 70.2 67.6 60.6 49.2 2 23.3 25.3 36.1 45.7 53.7 67.8 69 66.8 60.7 48.1 3 22.2 24.1 34.9 44.4 52.6 66.7 68.3 65.9 59.9 47.6 4 21.2 23.2 33.8 43.5 51.5 65.7 67.9 65.1 59.2 46.8 5 20.7 22.9 32.8 42.7 50.8 64.8 67.2 64.5 58.6 46 6 20.3 22.4 31.7 42.4 50.2 64.3 66.7 63.9 58.1 45.4 7 20.1 21.8 31.2 42.4 51.9 66.4 68 64.5 58 44.8 8 20.1 21.5 31.5 45 55.3 69.8 71 68 60.1 46.1 9 21.4 23.1 35.2 48.4 58.2 73 74.4 71.9 63.7 50.8 

10 25.8 25.6 38.9 51.4 61.8 75.9 77.5 75.7 67.6 55.4 11 30.3 28.6 42.7 54.3 64.7 78.4 79.9 78.7 71.3 59.7 12 34.4 31.7 46.2 56.7 66.7 80.8 82.2 80.7 74.1 63.1 13 38 34.1 48.9 59.3 68 82.3 84.1 82.2 76.2 65 14 40.7 36.2 51 61.1 69.4 83.3 85.4 83.5 77.6 66.4 15 42 37.6 52.4 62.5 70.8 84 86.4 84.1 78.3 67.3 16 42 38.1 52.9 63.4 71.7 84.4 86.5 84.3 78.4 67.4 17 41.1 37.8 52.7 63.3 71.8 84.3 86 84 77.8 66.3 18 37.5 36.4 51.6 62.4 71 83.3 85 82.7 75.7 63.3 19 33.3 33.6 48.8 60.1 69.1 81.8 83 79.8 71 58.4 20 30.9 31.9 45.4 56.5 65.3 78.6 79.7 75.8 66.8 55.4 21 29 30.5 43.5 54 61.5 74.6 76 72.5 65 53.9 22 27.8 29.5 41.9 52.3 59.1 72.5 74 70.7 63.4 52.6 23 26.5 28.2 40.8 50.5 57.4 71.1 72.7 69.4 62.4 51.4 24 25.4 27.7 39 49.1 56 69.8 71.3 68.5 61.2 50.3 
G-22 

Table 20 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Charles County (MOVES Inp2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 67.5 75.8 71.7 70.5 76.6 77.3 83.3 85.5 87.9 76.1 2 68.2 77 72.1 72.8 76.5 78.9 84.1 86.4 88.2 77.8 3 69.6 77.5 73.5 74.4 77.9 80.5 84.9 86.9 88.8 78.9 4 70.7 78.1 74.9 75.3 79.3 82.1 85.2 88.1 89.4 79.5 5 71.6 78.1 76.4 75.8 79.8 82.9 86.4 88.4 90.1 81 6 71.9 78 77.5 76.3 81 84.1 86.7 89 90.4 81.9 7 71.6 78.7 78.2 77 79.9 81.9 85.2 88.1 90 83.1 8 71.6 78.3 78.2 73 75.5 76.3 80.2 84 88.8 82.6 9 70.5 76.7 74.7 67.9 71.4 70.6 73.8 76.5 83.8 76.8 

10 66.2 73.8 69.8 63.9 64.7 65.5 68.2 69 76.3 67.9 11 61.3 70.1 63.8 60.2 59.8 60.5 63.5 62.9 69.2 59.8 12 56.4 66.7 58.8 57.5 57 55.9 59.5 58.5 63.9 53.4 13 52.5 64 55.1 54.7 55.9 53.1 56.6 55.9 59.8 49.9 14 49.9 61.3 53 52.7 54.3 51.7 54.4 54 57.3 47.6 15 48.1 59.5 51.6 50.9 52.7 50.1 53.1 52.9 56 46.3 16 47.1 58.9 51.4 49.5 51.7 49.2 52.9 53 55.6 46 17 47.3 59.5 51.8 49.1 50.8 49.2 53.8 53.9 57.1 47 18 50.9 61.1 53.5 50.3 50.7 50.3 55.5 56.4 61.6 52.2 19 55.7 65.2 57.5 53.3 53.1 53.2 60 62.4 71.9 61 20 58.6 68.1 62.3 58.2 59 59.3 66.8 71.2 80.5 66.9 21 61.1 70.6 64.9 61.5 65.4 66.9 74 77.6 83.5 69.3 22 62.6 72.3 67.1 63.7 70.2 71.1 77.4 81.3 85.6 71.1 23 64 73.7 68.6 66.6 72.9 73.5 79.2 83.3 86.1 72.9 24 65.6 74.9 70.7 68.2 75 76 81.1 84.7 87.6 74.7 
G-23 

Table 21 – Average Monthly Temperatures by Hour of the Day for St. Louis County in Fahrenheit (MOVES Inp

2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 25.5 28.1 39 48.2 56.2 70.2 71.8 68.8 62.4 50.7 2 24.5 26.6 37.3 46.2 55 69.1 70.6 68.1 62.5 49.8 3 23.6 25.2 36.1 45.1 53.8 68 69.9 67.2 61.6 49.1 4 22.7 24.5 35.1 44.3 52.8 67 69.6 66.5 60.9 48.4 5 21.9 23.9 34.2 43.6 52.1 66.1 68.9 65.9 60.4 47.6 6 21.4 23.4 33.1 43.3 51.6 65.6 68.4 65.3 59.9 47.1 7 21.2 23.1 32.6 43.3 53.2 67.7 69.7 65.8 59.8 46.6 8 21.2 22.7 32.9 45.7 56.5 70.9 72.5 69.4 61.9 47.9 9 22.5 24.1 36.4 48.9 59.4 73.9 75.7 72.8 65.2 52.2 

10 26.6 26.7 39.8 51.8 62.5 76.8 78.5 76.6 68.7 56.7 11 30.8 29.5 43.3 54.6 65.2 79.3 81 79.5 72.2 60.7 12 34.9 32.5 46.7 56.8 67.1 81.6 83.1 81.4 74.8 63.9 13 38.2 35 49.4 59.3 68.4 83.1 84.8 83 76.8 65.8 14 41 37.1 51.3 61 69.4 84 86.2 84.1 78.3 67.2 15 42.5 38.5 52.7 62.4 70.8 84.8 87.2 84.8 79 67.9 16 42.5 39 53 63.2 71.6 85 87.3 84.9 79 68.1 17 41.6 38.6 53 63.1 71.9 84.9 86.8 84.6 78.4 67 18 38.1 37.2 51.7 62.4 70.9 84 85.9 83.2 76.3 64.2 19 34.2 34.6 49.1 60.1 69.3 82.5 83.9 80.5 72.3 59.9 20 31.8 32.9 46.3 56.8 65.6 79.5 80.7 76.8 68.5 57.1 21 30.1 31.6 44.4 54.4 62.5 76 77.4 73.9 66.6 55.5 22 29.2 30.8 42.6 52.8 60.2 73.9 75.8 72.1 65.2 54.1 23 27.9 29.5 41.7 51 58.4 72.4 74.4 70.8 64.1 52.9 24 26.8 28.8 40 49.6 57.2 71.2 73 69.8 63.1 51.7 
G-24 

Table 22 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Louis County (MOVES Inpu

2017, and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 67.3 75.9 71.8 70 75.9 75.8 82.3 85 87.4 75.9 2 68.1 77.1 72.2 72.6 76 78.1 83.3 85.8 87.7 77.6 3 69.5 78.3 73.3 74.2 77.4 80 84.2 86.7 88.6 79.1 4 70.3 78.5 74.4 74.7 78.5 81.3 84.7 87 89.5 79.6 5 71.5 78.5 75.9 75.6 79.3 82.4 85.9 87.9 89.8 81.1 6 72 78.8 77.7 76.1 80.5 83.3 86.2 88.4 90.1 82 7 71.7 79.1 78 76.4 79.4 81.1 84.7 88.2 90.1 82.9 8 71.4 78.4 78.6 72.5 75 75.6 79.8 83.2 88.6 82.4 9 70.3 77.2 74.8 67.9 71 70 73.4 76.3 83.3 76.7 

10 66 74.2 69.9 63.7 65 64.7 67.9 68.6 76.2 67.6 11 61.4 70.5 64.6 60.2 60 60 63.2 62.8 69.1 59.4 12 56.7 67.1 59.6 57.8 57.5 55.2 59.2 58.4 63.5 53.1 13 52.8 64.6 56 54.9 56.4 52.3 56.3 55.8 59.6 49.5 14 49.8 62 53.9 53.1 55.1 51.3 54.2 53.9 57 47.2 15 47.8 59.9 52.4 51.3 53.5 49.5 52.5 52.9 55.5 45.9 16 46.8 59 52.7 49.9 52.7 48.6 52.5 52.9 55.3 45.5 17 47.2 59.7 52.9 49.6 51.4 48.6 53.2 53.9 56.8 46.6 18 50.6 61.2 54.8 50.5 51.4 49.7 54.7 56.4 61.5 51.4 19 55.1 65.1 58.5 54 53.5 52.4 58.9 62 70.6 59.1 20 58.2 68.2 62.5 58.2 59 57.9 65.8 69.8 78.6 65.1 21 60.2 70.4 65.3 61.4 64.5 64.3 72.3 76.1 82.2 68.2 22 61.9 72.1 67.7 63.6 69.2 69 75.5 80 84.2 70.4 23 63.7 73.8 69.3 66.6 72.5 71.6 77.7 82.2 85.3 72.5 24 65.2 75 71.1 68.3 74.6 74.3 80.1 83.9 86.5 74.6 
G-25 

Table 23 – Average Monthly Temperatures by Hour of the Day for St. Louis City in Fahrenheit (MOVES Inputs 

and 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 25.9 28.9 40.2 48.1 56 70.1 72.4 69.2 62.7 51.5 2 25 27.5 38.4 46.2 54.9 69.1 71.2 68.5 62.9 50.7 3 24 26.3 37.4 45.3 53.8 68 70.6 67.7 62.2 49.9 4 22.9 25.4 36.3 44.3 52.9 67 70.1 67 61.5 49.4 5 22.4 24.9 35.6 43.7 52.2 66.2 69.6 66.3 61 48.6 6 21.7 24.4 34.5 43.4 51.8 65.6 69.1 65.9 60.6 47.9 7 21.5 23.8 33.9 43.7 53.6 67.9 70.6 66.5 60.5 47.5 8 21.3 23.5 34.2 46 57 71.2 73.5 70.2 62.6 48.8 9 22.8 24.9 37.7 49.2 59.8 74.4 76.5 73.7 66 53.3 

10 27 27.5 41 52.1 62.9 77.4 79.2 77.5 69.5 57.8 11 31 30.3 44.3 54.8 65.6 79.9 81.6 80.3 72.9 61.8 12 35 33 47.4 57 67.7 82.1 83.6 82.3 75.4 64.8 13 38.1 35.5 50.1 59.3 68.7 83.8 85.2 83.7 77.3 66.8 14 41.1 37.4 51.8 61 69.7 84.5 86.7 84.9 78.7 68.1 15 42.7 38.8 53.3 62.4 71.1 85.3 87.6 85.5 79.4 68.8 16 42.5 39.3 53.6 63.2 71.7 85.4 87.8 85.5 79.5 68.8 17 41.6 39.1 53.4 62.9 72 85.4 87.5 85.3 78.7 67.9 18 38.1 37.7 52.2 62.1 71.2 84.4 86.4 83.8 76.8 65.1 19 34.3 35.1 49.5 60.1 69.4 82.9 84.5 81.2 72.5 60.7 20 32.1 33.4 47 56.7 65.8 79.8 81.4 77.2 68.5 57.8 21 30.4 32.2 45 54.5 62.5 76 77.9 74.3 66.8 56.2 22 29.5 31.3 43.5 52.8 60.2 73.6 76.2 72.3 65.5 54.9 23 28.3 30.1 42.6 51 58.3 72.2 74.8 71.2 64.3 53.6 24 27.2 29.6 41.1 49.5 57.1 71 73.6 70.3 63.4 52.4 
G-26 

Table 24 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Louis City (MOVES Inputs fand 2022 On-Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 68 76.6 72.6 71.4 77 76.6 83.4 85.9 87.7 76.9 2 69 78.1 73.2 73.8 76.9 78.7 84.2 86.5 87.7 78 3 69.8 79 74 74.8 78 80.8 85.4 87 88 79.7 4 70.9 79 75.2 75.9 79.1 81.9 85.6 87.6 88.9 80.3 5 72.1 78.9 76.3 76.5 79.9 82.7 86.5 88.5 89.5 81.5 6 72.4 79.2 78.4 77.4 80.5 83.9 86.8 88.5 89.8 82.7 7 72.7 79.5 79 77.1 79.4 81.7 85.1 88.2 89.5 83.3 8 72.3 79.1 79.4 73.4 75.1 75.9 80.1 83.3 88.3 83.1 9 70.9 77.9 75.6 68.3 71 70 74 76.4 83 77 

10 66.7 74.9 70.6 64.2 64.8 64.5 68.4 68.9 75.7 67.4 11 61.9 71.5 65.5 60.7 60.1 59.6 63.7 63.1 68.9 59.1 12 57.4 68.3 60.7 58.5 57.1 55.3 59.7 58.7 63.6 52.8 13 53.7 65.5 57 55.7 56.4 52 57.1 56.3 59.7 48.9 14 50.6 63.3 55.1 53.7 55.1 51.2 54.6 54.2 57 46.4 15 48.4 61.4 53.4 51.7 53.7 49.5 53.1 53.5 55.5 45.5 16 47.8 60.3 53.4 50.4 52.9 48.9 52.7 53.5 55.1 45.3 17 48 60.7 53.8 50.2 51.8 48.9 53.4 54.2 56.8 46.4 18 51.2 62.1 55.8 51.4 51.4 49.9 55.2 57.1 61.6 51.3 19 55.9 66 59.7 54.8 53.9 52.4 59.2 62.6 71.1 59.4 20 58.7 69.2 63.6 59.6 59.7 58.2 66.3 71.1 79.7 65.7 21 60.8 71.1 66.4 62.1 65.5 65 73.6 77.5 83.4 68.8 22 62.5 73.1 68.7 64.8 70 70.2 76.8 81.4 84.8 71 23 64.3 74.8 70.2 67.7 73.6 72.8 79.1 83.1 86.2 73.1 24 66.1 75.7 71.8 69.4 75.7 75.3 81 84.8 87.1 75.5 
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 inventory data used in this demonstration was 

calculated with MOVES 2010b. The 2011 mobile emissions were calculated for the purposes of 

the 2011 National Emissions Inventory; however they are displayed in this demonstration in 

order to provide a broad range of years demonstrating the continual decline 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 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 2011 was developed from Missouri Department of 

Transportation traffic distribution data for state-owned roads. The 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 Missouri Department of Revenue. 

The list of vehicle identification numbers provided by the Missouri Department of Revenue was 

converted into Mobile6 vehicle classifications 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 was 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 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 input can be found in the I/M input table development protocol (Attachment #2). 

MOVES 2010b base data was used for all other inputs to calculate the 2011 mobile source 

emissions, after reviewing the data to ensure accuracy. 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 database 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 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 road 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 been created, MOVES 2010b was ran and all 
G-28 

months for 2011 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 2011 

.
G-29 

Section 2: Data Used to Develop the MOVES County Database Manager Inputs for the St. Louis Nonattainment Area CWhen using MOVES 2010b to calculate the on-road mobile source VOC emissions, default data was used in the county 

Average Speed Distribution, Fuel Supply, Fuel Formulation, VMT Monthly Distribution, VMT Daily Distribution, and Vall five counties. For all county database manager input tables developed by the Air Program for 2011, the data used to listed 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 County 

YearID SourceTypeName SourceTypeID Franklin Jefferson St Charles St Louis County 

2011 Motorcycle 11 3,350 7,286 8,742 14,882011 Passenger Car 21 37,614 82,976 143,363 472,092011 Passenger Truck 31 41,668 76,955 112,323 287,932011 Light Commercial Truck 32 15,143 26,379 36,070 91,902011 Refuse Truck 41 12 44 36 72011 

Single Unit Short-haul Truck 42 35 131 108 22

2011 

Single Unit Long-haul Truck 43 258 490 504 1,99

2011 Motor Home 51 20 17 16 42011 School Bus 52 668 737 820 2,842011 Transit Bus 53 50 55 60 212011 Intercity Bus 54 38 61 73 292011 

Combination Short-haul Truck 61 335 280 270 67

2011 

Combination Long-haul Truck 62 276 219 210 45
G-30 

Table 2 – 2011 Annual VMT by HPMS Vehicle Type, County, and Year (MOVES Inputs for 2011 On-Road Mobile So

 HPMSBaseYearVMT by County 

HPMSVtypeID HPMSVtypeName YearID Franklin Jefferson St. Charles St. Louis 

10 Motorcycles 2011 9,402,897 14,491,095 24,790,826 80,646,3720 Passenger Cars 2011 665,926,569 1,026,279,979 1,755,721,576 5,711,491,3330 

Other 2 axle-4 tire vehicles 2011 255,497,009 393,754,323 673,620,235 2,191,336,13

40 Buses 2011 4,851,597 7,476,945 12,791,280 41,610,9750 Single Unit Trucks 2011 43,124,442 66,460,408 113,697,992 369,867,9260 Combination Trucks 2011 121,423,920 187,130,150 320,135,292 1,041,423,63
G-31 

Table 3 – 2011 Inspection and Maintenance Data (MOVES Inputs for 2011 On-Road Mobile Source VOC Emissions) 

Pol Process ID 

State ID 

Year ID 

Source Type ID 

Fuel Type ID 

IM Program ID 

Inspect Freq 

Test Standards ID 

Beg Model Year ID 

End ModYear ID 

101 29 2011 21 1 1 1 11 1971 19101 29 2011 21 1 10 2 51 1996 20101 29 2011 31 1 1 1 11 1971 19101 29 2011 31 1 10 2 51 1996 20101 29 2011 32 1 1 1 11 1971 19101 29 2011 32 1 10 2 51 1996 20102 29 2011 21 1 1 1 11 1971 19102 29 2011 21 1 10 2 51 1996 20102 29 2011 31 1 1 1 11 1971 19102 29 2011 31 1 10 2 51 1996 20102 29 2011 32 1 1 1 11 1971 19102 29 2011 32 1 10 2 51 1996 20112 29 2011 21 1 7 1 41 1971 19112 29 2011 21 1 8 2 43 1996 20112 29 2011 31 1 7 1 41 1971 19112 29 2011 31 1 8 2 43 1996 20112 29 2011 32 1 7 1 41 1971 19112 29 2011 32 1 8 2 43 1996 20113 29 2011 21 1 7 1 41 1971 19113 29 2011 21 1 8 2 43 1996 20113 29 2011 31 1 7 1 41 1971 19113 29 2011 31 1 8 2 43 1996 20113 29 2011 32 1 7 1 41 1971 19113 29 2011 32 1 8 2 43 1996 20
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 0.29129
G-33 

Table 5 –Vehicle Age Distribution (MOVES Inputs for 2011 On-Road Mobile Source VOC Emissions) 

Source Type ID 

AgeID 11 21 31 32 41 42 43 51 52 53 

0 0.0436 0.0639 0.076398 0.074052 0.0348 0.0348 0.013131 0.059681 0.068461 0.06768 1 0.0379 0.0545 0.056036 0.052896 0.0246 0.0246 0.003494 0.034957 0.035371 0.036001 2 0.0789 0.0518 0.038122 0.037103 0.0132 0.0132 0.036216 0.033113 0.035872 0.035904 3 0.094 0.0677 0.066376 0.066571 0.0184 0.0184 0.069138 0.047342 0.047587 0.047801 4 0.0883 0.0671 0.060881 0.060684 0.0405 0.0405 0.098013 0.136686 0.128434 0.129911 5 0.0921 0.0667 0.07325 0.0735 0.0369 0.0369 0.056028 0.068436 0.076964 0.077734 6 0.0699 0.0625 0.074895 0.073397 0.0231 0.0231 0.102831 0.076632 0.074017 0.075087 7 0.0622 0.0663 0.069494 0.069842 0.0504 0.0504 0.120834 0.066117 0.056923 0.057919 8 0.0665 0.0586 0.067393 0.067372 0.0575 0.0575 0.078472 0.067755 0.055622 0.056864 9 0.0645 0.0693 0.072855 0.071667 0.0255 0.0255 0.040211 0.036375 0.03931 0.040733 

10 0.0451 0.0572 0.057108 0.058032 0.0306 0.0306 0.047493 0.047575 0.047842 0.047521 11 0.0421 0.0618 0.052988 0.05455 0.0423 0.0423 0.066277 0.075638 0.060895 0.060468 12 0.0294 0.0462 0.042401 0.044027 0.0287 0.0287 0.036229 0.046378 0.040119 0.039618 13 0.026 0.0431 0.037305 0.036396 0.0211 0.0211 0.024733 0.034504 0.030644 0.030445 14 0.0176 0.0315 0.027359 0.028988 0.0197 0.0197 0.020917 0.026129 0.032284 0.032271 15 0.0195 0.028 0.024189 0.025117 0.0357 0.0357 0.024419 0.019853 0.024916 0.024896 16 0.0135 0.0233 0.017828 0.019102 0.0291 0.0291 0.019666 0.021785 0.023893 0.023282 17 0.0137 0.0201 0.017869 0.018499 0.0451 0.0451 0.016002 0.014999 0.013556 0.013504 18 0.0107 0.0128 0.010756 0.010998 0.0456 0.0456 0.010873 0.012056 0.01322 0.013077 19 0.0085 0.0124 0.010364 0.010483 0.0282 0.0282 0.008743 0.009118 0.00864 0.008691 20 0.0057 0.0078 0.006807 0.006906 0.0527 0.0527 0.008974 0.008864 0.010739 0.010809 21 0.0068 0.0074 0.00685 0.007057 0.0644 0.0644 0.014947 0.009824 0.014223 0.013313 22 0.0051 0.0048 0.00685 0.006959 0.0367 0.0367 0.016863 0.009534 0.012041 0.011208 23 0.0054 0.0042 0.009505 0.00924 0.0616 0.0616 0.002219 0.008127 0.010536 0.009934 24 0.005718 0.003675 0.011175 0.010707 0.103394 0.103394 0.00104 0.007278 0.009543 0.008907 25 0.006054 0.003216 0.002712 0.002851 0.030206 0.030206 0.000944 0.005649 0.008432 0.007738 26 0.00641 0.002814 0.00084 0.000986 0 0 0.000942 0.003298 0.007172 0.006438 27 0.006787 0.001296 0.00033 0.000461 0 0 0.00011 0.001451 0.001527 0.001481 28 0.007186 0 0.000239 0.000311 0 0 7.60E-05 0.001052 0.001112 0.001089 29 0.007609 0 0.00019 0.000219 0 0 4.67E-05 0.000785 0.000832 0.000836 30 0.013236 0 0.000635 0.001027 0 0 0.060118 0.009009 0.009272 0.008839 
G-34 

Table 6 – Average Monthly Temperatures by Hour of the Day for Franklin County in Fahrenheit (MOVES Input

Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 24.7 34.9 44.1 50.3 59.4 68.6 67.7 66.8 60.6 46.1 2 22.2 34.7 42 48.2 57.9 67.7 66.9 66.2 59.6 46.1 3 21.1 33.3 40.9 47.2 56.8 66.6 65.9 65.4 58.8 45.3 4 20.2 32.3 40.1 46.1 56 65.8 65.2 64.6 58 44.5 5 19 31 39.4 45.2 55 65.1 64.4 63.8 57.3 43.5 6 18.3 29.8 38.5 44.6 54.2 64.6 63.7 63.1 56.7 42.9 7 17.8 28.6 37.8 44.5 56 66.6 65.3 63.6 56.3 42.1 8 17.4 27.8 38.2 47.9 59.9 70.2 69 67.7 58.9 42.9 9 17.9 29.8 42.2 52.4 63.6 74 72.7 72.3 62.7 46 

10 21.8 34 46.6 56.2 66.8 77.3 75.7 76.2 66.7 49.3 11 26.1 38.2 50.8 59.8 69.7 80 78.4 79.2 70.4 52.5 12 30.3 42.4 54.6 62.6 72 82.4 80.2 81.6 73.2 55.3 13 33.9 45.6 57.4 64.6 73.8 84.3 81.9 83.4 75.1 57.4 14 36.7 48.4 59.8 66.1 75.5 85.7 83 84.6 76.5 59 15 38.6 50.5 61.2 66.7 76.6 85.9 83.7 85.4 77.3 59.9 16 39.7 51.3 61.8 66.8 76.7 86.2 83.8 85.4 77.4 60.1 17 39.2 51 61.5 66.4 76.3 86.1 83.5 85 76.7 59.3 18 36 48.8 59.6 65.3 75.5 85 82.9 83.7 74.9 57.2 19 32.4 44.8 55.9 63.1 73.4 83.1 81.2 80.9 71.1 53.7 20 30.5 42.2 52.1 59.6 69.5 79.9 77.8 76.2 67.1 51.6 21 28.9 40.4 49.8 56.9 66.1 75.6 73.6 72.8 65.4 50.1 22 28 38.7 47.9 54.8 64 73.2 71.4 70.9 63.8 49 23 27 37.2 46.4 53 62.2 71.4 69.9 69.5 62.7 47.9 24 25.7 35.9 45.1 51.4 60.7 69.8 68.6 68 61.6 47.1 
G-35 

Table 7 – Average Monthly Percent Relative Humidity by Hour of the Day for Franklin County (MOVES Inputs Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 68.4 68.5 65 69.7 78.7 82 84.3 86.1 83.9 80.7 2 69.9 69 67.4 70 80.7 83.4 84.9 87.2 84.7 81.6 3 70.4 70.3 69.2 71.3 82.1 84.8 86 87.8 85.6 83.2 4 71.3 71.1 70.5 72.6 82.9 86 86.6 88.7 86.5 83.8 5 72.1 72.8 71.9 73.9 83.8 86.9 87.5 89.6 87.4 84.7 6 72.3 73.6 73 75.1 84.7 87.5 88.1 90.3 88 85 7 72.6 74.1 73.8 75.6 83.3 85.7 87.2 90 88.7 85.6 8 72.9 74.6 74.1 72.8 77.3 79.9 81.5 85.5 86.9 85.3 9 72.9 72.9 69.9 66.5 69.9 73.5 74.7 78.4 81.6 81.6 

10 69.6 67.5 63.5 61.4 63.9 68.2 68.7 71.5 74.9 77 11 64.8 62.4 57.8 56.7 58.9 64.4 64 65.9 67.9 71.6 12 60 57.3 52.9 53.1 55.3 60.6 60.7 61.7 62.4 67.4 13 56 53.9 48.8 50.8 52.6 58 58.1 58.7 59.2 64.4 14 52.8 50.9 45.6 49 50.4 55.8 56.6 56.4 56.7 62.2 15 50.9 49 43.8 48.2 48.9 55.1 55.7 55 55.2 60.9 16 49.6 48 42.8 48 48.6 54.6 55.7 54.6 55 60.5 17 50.1 48.1 42.6 48.3 49.1 54.5 56.1 55.1 56.3 61.5 18 53.8 50.8 44.7 49 50.4 56.1 57.4 57.3 59.6 65.1 19 58.3 56 48.9 51.8 53.9 59 61 62.7 67.7 70.9 20 61.1 59.4 53.6 56.2 60.8 64.8 67.8 71.2 75.8 74.3 21 63.8 62.2 57.2 60.3 67.2 71.9 75.8 77.1 78.4 76.5 22 65.1 64.6 59.8 63.3 71 75.8 79.7 79.9 81.1 77.5 23 66.1 66.3 61.7 66.1 74.2 78.3 81.6 82.1 81.9 78.7 24 67.7 68 63.6 68.2 76.8 80.1 83.5 84.3 83 79.5 
G-36 

Table 8 – Average Monthly Temperatures by Hour of the Day for Jefferson County in Fahrenheit (MOVES InpuMobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 25 33.3 42.6 49.7 60 69.5 67.9 66.8 61.9 47.2 2 22.6 33.2 40.6 47.8 58.9 68.6 67.3 66.1 61 47.2 3 21.6 32.2 39.5 46.9 57.9 67.8 66.3 65.3 60.2 46.3 4 20.8 31.2 38.9 45.9 56.9 67 65.6 64.5 59.5 45.8 5 19.9 30 38.3 45.2 56.2 66.3 64.9 63.8 58.8 44.9 6 18.9 28.7 37.5 44.7 55.3 65.8 64.3 63.3 58.2 44.2 7 18.3 27.5 36.8 44.7 57.2 67.9 65.8 63.8 57.9 43.4 8 17.8 26.7 37.5 47.8 60.6 71.2 69.2 67.7 60.4 44.3 9 18.4 28.7 41 51.8 64 74.8 72.7 71.9 64 47.2 

10 22.1 32.7 45.2 55.3 66.8 77.7 75.5 75.8 68 50.6 11 26 36.6 49 58.5 69.3 80.2 77.9 78.5 71.4 53.7 12 29.5 40.5 52.6 61.2 71.2 82.4 79.7 80.7 73.8 56.1 13 32.5 43.6 55.2 62.9 72.7 84 81.4 82.4 75.5 58 14 34.9 46.2 57.2 64.2 74.1 85.2 82.4 83.7 76.8 59.4 15 36.7 48.1 58.7 64.8 75.1 85.5 82.9 84.4 77.6 60.4 16 37.5 48.9 59.4 64.9 75.2 85.6 83 84.4 77.7 60.6 17 37 48.6 59 64.2 74.7 85.5 82.9 83.7 77.1 59.8 18 34.3 46.6 57.2 63.4 73.8 84.2 82 82.4 75.5 57.7 19 31.3 42.6 53.8 61.4 72.1 82.8 80.6 79.7 71.9 54.3 20 29.5 40.1 50.2 58.2 68.6 79.8 77.5 75.3 68.2 52.5 21 28.2 38.5 47.9 55.8 65.7 76 73.7 72.3 66.5 51.1 22 27.6 37 46.1 54 63.8 73.8 71.6 70.5 65 50 23 26.8 35.8 44.6 52.3 62.5 72.1 70.1 69.1 63.9 49 24 26 34.5 43.4 50.8 61.1 70.6 68.8 67.7 62.9 48.1 
G-37 

Table 9 – Average Monthly Percent Relative Humidity by Hour of the Day for Jefferson County (MOVES InputMobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 68.8 69.2 65.1 70.2 79.4 81.8 84 85.5 83.3 80.1 2 70.3 69.7 67.2 70.3 80.7 83.2 84.3 86.9 84.5 81.4 3 71.1 70.2 68.8 71.5 82.5 84.3 85.7 87.5 85.1 83.2 4 71.6 71 70.1 72.9 83.6 85.5 86.3 88.4 86 83.2 5 71.9 72.4 71.2 73.9 84.2 86.6 86.9 89.3 86.9 84.1 6 72.4 73.1 72.3 74.8 85.4 87.2 87.2 89.9 87.5 84.7 7 72.6 73.3 73.4 75.4 83.9 85.2 86.3 89.6 88.1 85.3 8 73.2 74.2 73.1 72.5 77.7 79.4 80.9 85.2 86.3 85.1 9 73 72.5 69.2 66.5 70.4 72.8 74.2 78.1 81.1 81.7 

10 69 67.4 63.3 61.2 64.1 67.8 68.5 70.9 74.2 76.2 11 64.5 62.2 57.8 56.9 59.3 63.7 64.1 65.3 67.5 70.9 12 60.1 57.7 53 53.3 56 60.2 60.4 61.2 62.5 67.2 13 56.3 54.3 48.6 51.2 53.2 57.7 58 57.9 59.3 64.2 14 53.4 51.4 45.6 49.4 51.1 55.6 56.3 55.7 56.9 62.2 15 51 49.9 43.4 48.4 49.8 54.8 55.6 54.5 55.5 60.5 16 50.1 48.4 42.1 48.1 49.3 54.3 55.6 54.1 55.1 60.1 17 50.8 48.9 42.2 48.7 49.9 54.3 56 55 56 60.9 18 54.2 51.7 44.5 49.1 51.3 56 57.5 56.9 59.3 64.7 19 59.1 56.9 49 51.9 54.7 58.6 60.6 62.4 67.1 70.7 20 62 60.6 54 56.7 61.8 64.1 67.3 70.9 75.1 73.8 21 64.5 63.2 57.6 60.8 68.1 71.2 74.8 76.5 78.2 76 22 65.9 65.4 60 63.7 71.7 75 78.9 79.6 80.6 77 23 66.9 66.9 62.2 66.5 74.5 78.1 81.3 81.8 82 78.4 24 67.7 68.4 64.1 68.7 77.4 79.9 83.2 84 82.5 79.3 
G-38 

Table 10 – Average Monthly Temperatures by Hour of the Day for St. Charles County in Fahrenheit (MOVES In

Road Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 23.3 31.7 41.4 48.5 58.4 68.2 67 66 60.8 46.4 2 21.1 31.7 39.4 46.5 57 67.3 66.3 65.5 59.7 46.4 3 20 30.4 38.1 45.5 55.9 66.4 65.4 64.7 59 45.6 4 19.2 29.4 37.4 44.5 55 65.6 64.6 63.9 58.2 45.1 5 18 28 37 43.8 53.9 64.7 63.9 63.2 57.4 44.2 6 17.2 26.7 36 43.2 53.1 64.3 63.2 62.7 56.7 43.6 7 16.7 25.7 35.3 43.2 55 66.4 64.8 63.3 56.5 42.8 8 16.4 25 36 46.3 58.6 69.7 68.3 67.2 59.2 43.7 9 17 27 39.8 50.7 62.3 73.2 71.7 71.2 63.1 46.4 

10 20.5 31.2 44.3 54.3 65.5 76.4 74.4 74.8 67.2 49.8 11 24.3 35.4 48.4 57.7 68.2 79 76.8 77.4 70.7 52.7 12 27.8 39.4 51.9 60.4 70.3 81.3 78.8 79.6 73.3 55.2 13 30.8 42.8 54.8 62.4 72.2 83 80.4 81.5 75 57.2 14 33.1 45.6 56.7 63.8 73.8 84.3 81.4 82.9 76.4 58.6 15 34.9 47.5 58.3 64.4 75 84.4 81.9 83.6 77.3 59.6 16 35.8 48.5 58.7 64.5 75.1 84.8 82.1 83.6 77.5 59.8 17 35.3 48 58.3 63.9 74.6 84.8 81.9 83 76.9 59 18 32.6 45.5 56.6 63.1 73.8 83.8 81 81.9 75.2 56.9 19 29.3 41.3 52.9 61 71.9 82.1 79.6 79.1 71.4 53.6 20 27.8 39.1 49.3 57.7 68.2 79.1 76.5 74.9 67.2 51.8 21 26.3 37.4 47 55.1 64.8 75 72.6 71.7 65.5 50.4 22 25.7 35.7 45.2 53 62.8 72.7 70.5 70 63.9 49.3 23 25.1 34.2 43.6 51.3 61.1 71 69.1 68.6 62.8 48.1 24 24.1 32.9 42.5 49.6 59.6 69.3 68 67.2 61.7 47.3 
G-39 

Table 11 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Charles County (MOVES InpRoad Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 68.6 69.6 65.2 69.8 77.2 81.7 84.3 86.6 83.9 81.3 2 70.4 69.8 67.3 70.1 79.1 83.4 84.8 87.5 85.3 82.6 3 70.9 70.9 69.1 71.4 80.8 84.8 85.7 88.1 85.9 84.5 4 71.5 71.4 70.5 72.4 82 85.7 86.9 89.6 87.1 84.4 5 72 73.1 71.3 73.5 83.1 86.9 87.1 90.3 88.1 85.7 6 72.2 73.9 72.7 74.6 84.3 87.5 88 90.9 89 86 7 72.5 74.4 73.5 75.2 82.6 85.4 86.9 90.3 89.3 86.6 8 72.8 75 73.3 72.3 75.8 79.3 81.1 85.5 87.5 85.7 9 72.8 73.3 69.1 65.6 68 72.9 74.1 78 81.6 82.6 

10 69.7 67.8 62.7 60.2 61.4 67.6 68.1 70.8 74.4 77.3 11 65.2 62.3 57 55.5 56.6 63.8 63.5 65 67 71.9 12 60.7 57.6 52.3 52.2 53.2 59.8 59.9 60.6 61.6 67.9 13 56.8 53.9 47.6 49.7 50.5 57.4 57.2 57.4 58.1 65.1 14 53.6 50.9 44.8 47.9 48.5 55.2 55.6 54.8 55.9 62.9 15 51.6 49 42.8 47.1 46.8 54.5 55.1 53.6 54.2 61.3 16 50.4 47.4 42 46.9 46.5 53.8 54.9 53.1 53.7 60.7 17 51.2 48.1 42.1 47.4 47.2 53.6 55.3 53.7 55 61.5 18 54.9 51.7 44.4 48.1 48.5 55.2 57.1 55.7 58.2 65.3 19 59.9 57.1 49.2 50.9 51.7 57.9 60.2 61.6 66.3 71.4 20 62.8 60.5 54.5 56.1 58.7 63.6 67.2 70.3 75.8 74.6 21 65.4 63.1 57.7 60 65.3 71.3 75.7 76.4 78.9 76.8 22 66.5 65.8 60.1 63.1 69.3 75.2 79.6 79.3 82 78.2 23 67 67.6 62.1 65.9 72.8 78 81.5 81.7 82.5 79.6 24 68.1 68.8 63.7 68.3 75.3 79.8 83.2 84.6 83.3 80.1 
G-40 

Table 12 – Average Monthly Temperatures by Hour of the Day for St. Louis County in Fahrenheit (MOVES InpMobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 24.8 33.1 42.9 50.2 61 70.2 68.9 68.1 62.6 47.7 2 22.6 33.1 41.1 48.4 59.8 69.5 68 67.6 61.7 47.6 3 21.6 32 40 47.6 58.9 68.5 67.2 66.7 61 46.8 4 20.6 31 39.2 46.5 57.9 67.6 66.3 66 60.2 46.4 5 19.5 29.7 38.6 45.8 57.2 66.7 65.7 65.3 59.5 45.6 6 18.6 28.4 37.8 45.3 56.4 66.5 65.1 64.8 58.8 44.9 7 18.1 27.4 37.3 45.3 58.1 68.6 66.6 65.4 58.6 44.3 8 17.8 26.8 37.8 48.2 61.2 71.7 69.8 68.9 61.1 45.2 9 18.4 28.7 41.2 52.1 64.3 75 73 72.5 64.7 47.7 

10 21.7 32.3 45.3 55.4 66.9 78 75.5 75.9 68.5 50.8 11 25.5 36.2 49.2 58.5 69.3 80.4 77.8 78.5 71.6 53.8 12 28.6 40 52.6 61.1 71.2 82.7 79.6 80.6 74.1 56 13 31.6 43.2 55.1 62.9 72.6 84.4 81.3 82.4 75.6 58.1 14 33.9 46 57 64.2 74 85.6 82.3 83.6 76.9 59.4 15 35.5 47.6 58.5 64.9 75.1 85.7 82.8 84.4 77.7 60.5 16 36.4 48.4 59 65 75.2 85.8 82.9 84.3 78 60.6 17 35.9 48.1 58.7 64.3 74.7 85.8 82.7 83.7 77.4 59.7 18 33.4 45.8 57 63.4 74 84.8 81.9 82.5 75.9 57.8 19 30.5 42.1 53.6 61.5 72.4 83.3 80.6 79.9 72.4 54.8 20 28.9 40 50.3 58.5 69.2 80.6 77.7 76.1 68.9 53 21 27.6 38.5 48.2 56.3 66.6 77 74.3 73.4 67.2 51.7 22 27.2 36.9 46.3 54.5 64.8 74.8 72.2 71.7 65.8 50.7 23 26.6 35.7 44.8 52.9 63.5 73.1 70.9 70.4 64.7 49.5 24 25.6 34.4 43.7 51.3 62.2 71.5 69.7 69 63.6 48.6 
G-41 

Table 13 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Louis County (MOVES InpuMobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 69 70 65.1 70 77.4 80.7 82.9 84.9 82.8 80.5 2 70.6 70.3 67.3 70.3 79.3 81.8 83.7 86.1 84.2 82 3 71.4 71.1 68.5 71.3 81 83.5 84.9 87.3 85.1 83.9 4 72.3 71.6 70.1 72.6 82.2 84.9 86 88.5 86 84.2 5 72.5 72.9 71.2 73.7 83 86.4 86.3 89.4 87.2 85.1 6 73 74 72.3 74.8 84.5 86.7 86.9 90 88.1 85.8 7 72.9 74.3 73.1 75.4 82.8 84.4 86 89.7 88.4 86.1 8 73.2 75.1 73.2 72.5 76.1 78.6 79.8 85 86.7 85.1 9 73.3 73.5 69.2 66.2 68.4 72.3 73.7 77.9 80.9 82.1 

10 70.2 68.5 63.1 61 62.5 67.1 67.8 70.5 73.5 76.8 11 65.3 62.9 57.4 56.5 57.6 63.1 63.2 64.4 66.8 71.5 12 61.3 58.6 52.6 52.9 54.2 59.4 59.6 59.9 61.2 67.7 13 57.4 54.7 48.2 50.8 51.5 56.8 56.8 56.7 58 64.5 14 54.2 51.8 45.4 48.9 49.5 54.6 55.1 54.4 55.8 62.3 15 52.1 50 43 47.9 47.8 53.9 54.6 52.8 54.1 60.8 16 51 48.5 42.1 47.5 47.3 53.4 54.7 52.6 53.4 59.9 17 51.8 49.1 42 48.2 48.1 53.4 55.2 53.5 54.5 60.9 18 55.5 52.6 44.7 49.1 49.3 54.7 56.7 55.4 57.6 64.4 19 60.3 57.7 49.1 51.9 52.6 57.4 59.7 61.3 65.5 70 20 63.3 61.4 54.2 56.9 59.5 62.5 66.1 69.3 73.5 73 21 65.6 63.7 57.7 60.4 65.3 69.1 73.3 75 76.9 75.7 22 66.4 66.5 60.2 63.3 69.2 73.1 77.6 78.1 79.8 77.1 23 67.2 67.7 62.3 66.3 72.5 76.3 79.9 80.5 81.2 78.5 24 68.2 69 64.2 68.8 75.3 78.3 82.1 83.2 82 79.3 
G-42 

Table 14 – Average Monthly Temperatures by Hour of the Day for St. Louis City in Fahrenheit (MOVES Inputs 

Mobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 25.9 34.7 44.1 51.8 62.1 71.4 70 69.2 64 49 2 23.7 34.7 42.3 50.1 61 70.5 69.4 68.8 63.2 48.9 3 22.8 33.7 41.4 49.4 60.1 69.7 68.5 67.9 62.3 48.1 4 21.9 32.6 40.7 48.4 59.2 68.8 67.7 67.2 61.7 47.7 5 21 31.5 40.2 47.8 58.5 67.9 67.1 66.5 61 47 6 19.9 30.3 39.5 47.3 57.7 67.7 66.6 66.1 60.4 46.3 7 19.3 29.3 39 47.3 59.5 69.9 68.1 66.7 60.2 45.6 8 18.9 28.5 39.6 50 62.7 73.3 71.2 70.3 62.7 46.6 9 19.6 30.5 42.8 53.8 65.7 76.6 74.4 73.9 66.1 49.2 

10 22.9 34 46.6 56.7 68.2 79.6 77 77.3 69.9 52.3 11 26.5 37.5 50 59.7 70.5 81.9 79.3 79.7 72.9 55 12 29.5 40.8 53.2 62 72.2 84.1 80.9 81.7 75.1 57.2 13 32.4 43.9 55.6 63.4 73.5 85.9 82.6 83.3 76.7 59 14 34.5 46.5 57.3 64.7 74.8 87 83.5 84.5 77.7 60.2 15 36 48 58.8 65.4 75.8 87.1 84 85.2 78.5 61.2 16 36.7 48.6 59.3 65.4 75.8 87.1 84 85.1 78.7 61.3 17 36.3 48.3 58.9 64.8 75.3 87.1 83.9 84.4 78.2 60.5 18 33.9 46.2 57.4 63.9 74.6 86 83.1 83.3 76.7 58.5 19 31.2 42.7 54.3 62.2 73.1 84.5 81.8 80.7 73.3 55.5 20 29.8 40.7 51.1 59.4 69.8 81.7 78.9 76.9 69.9 53.9 21 28.5 39.3 49 57.5 67.3 78 75.5 74.3 68.3 52.6 22 28.2 38.1 47.2 55.7 65.6 75.9 73.5 72.7 67 51.7 23 27.4 37.2 45.9 54.3 64.4 74.1 72 71.5 65.8 50.7 24 26.7 36 44.8 52.9 63.2 72.6 70.9 70.1 65 49.9 
G-43 

Table 15 – Average Monthly Percent Relative Humidity by Hour of the Day for St. Louis City (MOVES Inputs fMobile Source VOC Emissions) 

 MonthID 

HourID 1 2 3 4 5 6 7 8 9 10 

1 69.2 70.2 65.5 71 78.7 81.1 83.6 85.3 83.2 80.6 2 71 70.5 67.4 70.5 80.6 82.5 83.8 86.5 84.3 81.8 3 71.6 71 69 71.8 82.3 83.9 85 87.3 85.2 83.7 4 72.4 71.7 70 72.8 83.5 85 86.1 88.8 86.1 84.3 5 72.6 72.8 71.1 74.2 84 86.4 86.4 89.8 87 84.9 6 72.8 73.9 72.2 75 85.5 86.7 86.7 90.4 88.2 85.5 7 73.1 74.4 73 75.6 83.8 84.5 85.5 89.8 88.5 86.5 8 73.4 75.3 73.1 72.7 77 78.5 80 85.1 86.4 85.5 9 73.1 73.3 68.9 66.2 69.4 72 73.6 77.7 80.7 81.8 

10 69.7 68.4 63 61.4 63.1 67 67.7 70.4 73.4 76.1 11 65.2 63.1 57.7 56.9 58.2 63.1 63 64.3 67 71 12 61.5 59.2 52.7 53.6 54.9 59.4 59.8 60.1 61.6 67.4 13 57.5 55.2 48.3 51.8 52.4 57 56.7 57 58.4 64.1 14 54.7 52.5 45.4 49.9 50.3 54.7 55.3 54.7 56.3 62.1 15 52.4 50.7 42.9 48.7 48.8 54.1 54.6 53.3 54.6 60.6 16 51.4 49.3 41.9 48.5 48.5 53.7 54.8 53.1 54.1 60 17 52.3 49.7 42 49.2 49.5 53.7 55.4 53.9 55 61 18 55.8 53.4 44.4 50 50.6 55.3 57 55.9 58.2 64.5 19 60.4 58.5 49.1 52.8 54 57.8 59.9 62.1 65.9 70.6 20 63.1 62 54.3 57.7 61.1 63 66.3 70.1 74.2 73.7 21 66 64.4 58 61.3 66.8 69.9 73.4 75.9 77.5 75.8 22 66.5 66.6 60.9 64.2 70.9 73.7 77.9 79 80.2 77.2 23 67.6 67.6 62.7 67.3 73.9 77.2 80.3 81.1 81.8 78.6 24 68.4 69.2 64.6 69.5 76.5 79 82.8 83.6 82.4 79.4 
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 assumptions 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 and methods to be used when developing the I/M 

input table for MOVES 2010. This guidance has been 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 MOVES. 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 database 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 only 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 OBD 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 associated pollutant process IDs were still included 

in the I/M input table, but they were “turned off”. 

Source Type ID 

The St. Louis I/M program includes passenger cars and 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 passenger cars, passenger trucks, and light commercial 

trucks (IDs = 21, 31, and 32). 

Fuel Type ID 

The St. Louis I/M program is applicable to both 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 every 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 program 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) were 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 MOVES 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 model 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 ending model year would always be two years less than the emissions 

inventory year that is being developed. Therefore, for the tests for gasoline vehicles, the 

beginning model year is 1996 and the ending model year is two years earlier than the year for 

which MOVES is being run, and the for diesel vehicles the beginning model year is 1997 and 

the ending model year is two years earlier than the year for which MOVES is being run. 

Compliance Factor 

According to page 39 of the MOVES guidance document 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 factor for each source type included in the I/M 

program, the compliance rate, waiver rate, and regulatory 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 calculated with the following equation: 

Compliance Rate = Number of vehicles that were 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 that is theoretically subject to I/M first needed to be determined. 

In May 2009, the Missouri Department of Revenue (DOR) Vehicle Registration database was 

queried and a VIN decoder was used to separate the vehicle counts into Mobile 6.2 vehicle 

classes by model year. In the St. Louis nonattainment area, the Mobile 6.2 vehicle classes that 

are subject to I/M include 1996 and newer light duty gasoline vehicles, light duty gasoline trucks 

Class 1, light duty gasoline trucks Class 2, light duty gasoline trucks Class 3, light duty gasoline 

trucks Class 4, as well as 1997 and newer light duty diesel vehicles, light duty diesel trucks Class 

1, light duty diesel trucks Class 2, light duty diesel trucks Class 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 generator 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 total number of vehicles that received waivers during the same time 

period. Table 2 below, was generated with data from this query. 

Table 2. Initially Tested Vehicles that Received 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 compliance 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 that fail an initial I/M test and do not pass a retest, 

but do receive a certificate of compliance. The waiver rate was determined by dividing the 

number of vehicles that received waivers from January 1, 2008 through December 31, 2009 by 

the total number of vehicles that were tested at least once during the same time period. 

Therefore, the waiver rate was calculated for the St. Louis I/M Program 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 accounts for the fraction of 

vehicles within a source type that are covered by the I/M program. Since the I/M program in St. 

Louis exempts vehicles with a gross vehicle weight rating above 8,500 lbs., the compliance 

factor needs to reflect the percentage 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 corresponding 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% oxygen 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 the 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 summarized 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 (Excludes 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 Protocol for 2008 and 2022 for the St. Louis, 

Missouri Five-County Nonattainment Area 

Ozone and PM2.5 Maintenance Plan Work Share St. Louis, Missouri Five-County Area 

Nonroad Modeling for Inventory Development 

For this modeling exercise, the EPA Region 7 utilized the NONROAD2008a model to calculate 

an ozone and PM2.5 nonroad inventory in five counties in the St. Louis nonattainment area for 

the 1997 PM2.5 annual and 1997 Ozone NAAQS. The NONROAD2008a model provides the 

emissions for all nonroad source categories except aircraft, commercial marine vessel, and 

railroad locomotive. 

In running the NONROAD model, the user must specify a modeling scenario by the inventory 

year, geographic area (nation, state, county), period (annual, seasonal, monthly, daily), and the 

equipment categories. For all other required variables, the NONROAD model provides default 

input values. For the following modeling exercises, fuel parameters (Reid Vapor Pressure 

(RVP), oxygen weight, sulfur content, ethanol volume 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 years 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. Louis City in St. Louis, Missouri. 

For modeling ozone precursor pollutants, temperatures and fuel characteristics representative of 

each county during an ozone summer weekday, were entered into NONROAD2a and modeled to 

calculate an ozone season weekday emissions for nonroad sources. Minimum, maximum, and 

average temperatures for a typical summer season were provided by MDNR (see attachment). 

Modeling input parameters are as follows: 

Table B-27 

NONROAD Model Temperature & Fuel Characteristic 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 PM2.5 / PM2.5 Precursor Emissions 

Methodology/Input Data: 

Nonroad mobile source emissions for the years 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. Louis City in St. Louis, Missouri. 

For modeling PM2.5 and PM2.5 precursor pollutants, temperatures and fuel characteristics 

representative of each county for each 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, seasonal 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 representative of each county 

were provided by MDNR. Modeling input parameters are as follows: 

Table B-28 

NONROAD Model Temperature & Fuel Characteristic 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 verified and correctly entered 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 performed 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 comments 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 electronically, use the links below the rule or to 

submit written comments see the address below.

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

This proposed amendment will remove the requirements for Stage II vapor recovery 

controls at gasoline dispensing facilities (GDFs) in the St. Louis area. Stage II systems 

control emissions of volatile organic compounds 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) determined that Onboard Refueling Vapor Recovery 

(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 controlling 

the vapor displaced during refueling that is built into newer motor vehicles. ORVR makes 

Stage II controls obsolete, and EPA’s widespread use determination allows the 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 Stage 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 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 storage 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 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 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. 

•

Proposed Rulemaking – Published in April 1, 2014 Missouri Register

Rulemakings on Public Notice - DNR Page 1 of 2

http://www.dnr.mo.gov/env/apcp/rulemaking.htm 4/7/2014
Technical Support Document

Additional Information on this rulemaking. 

Submit comments now

Submit written comments

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

10 CSR 10-6.165 (amendment) Restriction of Emission of Odors

This proposed amendment will remove the definitions of “Modification” and “Class IA 

concentrated animal feeding operation” found in 10 CSR 10-6.165, 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 accepted through close of business May 1, 2014.

Submit written comments about 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

Rulemakings on Public Notice - DNR Page 2 of 2

http://www.dnr.mo.gov/env/apcp/rulemaking.htm 4/7/2014
1

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 Notices Update - Missouri Air Conservation 

Commission Public Hearing, May 29, 2014

This is a courtesy copy of an email bulletin sent by Cheri Bechtel.

This bulletin was sent to the following groups of people:

Subscribers of Air Public Notices (579 recipients) 

Having trouble viewing this email? View it as a Web page.

MISSOURI AIR CONSERVATION COMMISSION 

WILL HOLD PUBLIC HEARING 

JEFFERSON CITY, MO -- The Missouri Air Conservation Commission will hold 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 commission will hear testimony related to the following 

proposed action(s): 

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

 

This proposed amendment will remove the requirements for Stage II vapor recovery controls at 

gasoline dispensing facilities (GDFs) in the St. Louis area. Stage II systems control emissions of 

volatile organic compounds 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) 

determined that Onboard Refueling Vapor Recovery (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 controlling the vapor displaced during refueling that is built into 

newer motor vehicles. ORVR makes Stage II controls obsolete, and EPA’s widespread use 

determination allows the 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 Stage 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 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 storage 
2

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 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 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 establishes requirements for the protection of visibility in Class I areas, 

consisting of national parks and wilderness areas. States 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 Class I areas by 2064. There are two Class I areas in Missouri: Hercules 

Glades Wilderness Area and Mingo National Wildlife 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 Class 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 five years since Missouri’s regional haze SIP was 

submitted to EPA. This 5-year progress report demonstrates that both of Missouri’s Class I areas are 

expected to meet their 2018 visibility goals based on control strategies currently in place, which 

largely consist of sulfur dioxide and nitrogen oxides emission reduction measures for utilities, 

industrial boilers, and other sources. 

 

* Missouri State Implementation Plan Revision – Marginal Area Plan for the 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 the emissions inventory and 

other marginal ozone nonattainment area requirements pursuant to Clean Air Act Section 182(a) for 

the Missouri portion of the St. Louis nonattainment area under the 2008 8-hour ozone national 

ambient air quality standard (NAAQS). The Missouri portion of the St. Louis nonattainment area 

includes the City of St. Louis and the Counties of St. Louis, St. Charles, Franklin, and Jefferson, 

which were designated as a marginal nonattainment 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 methods. 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 microns, 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 matter and, at the same time, designated it as a new Federal Equivalency 

Method. 

 

If the Commission adopts the action(s), it will be the Department’s intention to submit the action(s) to the 

U.S. Environmental Protection Agency to be included in Missouri’s State Implementation Plan unless 

otherwise noted above. 

 

Documents for the above item(s) will be available for review at the Missouri Department of Natural 
3

Resources, Air Pollution Control Program, 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 hearing testimony will be equally considered. 

 

Citizens wishing to speak at the public hearing should notify the secretary to the Missouri Air Conservation 

Commission, Missouri Department of Natural Resources, 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 presentations also provide a written 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 directly at (573) 751-4817, the Division 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 Commission Secretary, P.O. Box 176, Jefferson City, MO 65102. 

Hearing impaired persons may contact the program through Relay Missouri, (800) 735-2966. 

 

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This service is provided to you at no charge by Missouri DNR. 
 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 by

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 to

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, EPA

14 Promulgated Rule 40 CFR 51.102 for the purpose of

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

16 amendment, Control of Petroleum Liquid Storage,

17 Loading and Transfer; Missouri State Implementation

18 Plan Revision, Regional Haze Plan, 5-year Progress

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 Ambient

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, deposes

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 East

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

8 to present testimony for the proposed amendment to

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 proposed

14 amendment is the removal of requirements for Stage

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 refueling

23 vapor recovery, known as ORVR, is in widespread use

24 throughout the motor vehicle fleet for controlling

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 Stage II vapor 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]This [r]Rule [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]Store 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]Store 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:]

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

769

Proposed Rules

Proposed Amendment Text Reminder:

Boldface text indicates new matter.

[Bracketed text indicates matter being deleted.]

Under 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 a

citation to the legal authority to make rules. This appears following the text of the rule, after the word “Authority.”

Entirely 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.

An 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 agency

within a specified time, no less than thirty (30) days after publication of the notice in the Missouri Register. 

An 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.

MISSOURI

REGISTER

April 1, 2014

Vol. 39, No. 7
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

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]stationary 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 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.

(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.

(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]loading 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

C. Other equipment of an efficiency equal to or greater than

Page 770 Proposed Rules

April 1, 2014

Vol. 39, No. 7
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 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 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 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 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

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 may

approve 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 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);

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;]

[D.]C. [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] 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 Register
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] 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 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.

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

working order; and removed the “out-of-order” notice. The

staff director shall reinspect the previously marked “out-oforder” 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;

(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

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April 1, 2014

Vol. 39, No. 7
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-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 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 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 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 selfinspections 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.

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 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.

Page 773 April 1, 2014

Vol. 39, No. 7 Missouri Register
Installations 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, operators 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 permit

according 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 beginning

construction or modification 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] 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 diagrams

including 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 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] 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) [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;]

Detailed description of the storage 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 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.]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) and

maintained 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 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)] (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) years 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 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 [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 system

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April 1, 2014

Vol. 39, No. 7
modification 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 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[:], any modification—

(I) [Modifications t]That requires 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, 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] 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. 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 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;

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 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.

[(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.]

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; and

B. 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; and

B. 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]To 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

Page 775 April 1, 2014

Vol. 39, No. 7 Missouri Register
January 1, 1999, without an operating permit] thirty (30)

days of construction completion;

[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.]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 II

vapor recovery system is in place, a dynamic back pressure/liquid blockage 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 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.]B. Owners or operators of [A]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[; 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.]

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 H2O) 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 and

Stage 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 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.

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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 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 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)] (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 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 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-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 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.

AUTHORITY: section 643.050, RSMo [2000] Supp. 2013. Original

rule 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.

NOTICE OF PUBLIC HEARING AND NOTICE 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, Jefferson

City, MO 65102-0176. Email comments shall be sent to apcprulespn@dnr.mo.gov.

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and 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 waterfowl

hunting 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 education

certificate 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 February

10, 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 of

Natural 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 Storage Tank 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 with

most of the changes in the proposed amendment, but expressed concerns with the provisions for aboveground storage 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 Performance

Evaluation Testing Procedures (MOPETP). They expressed appreciation for the ongoing dialogue the department has maintained with

MPCA members and other interested parties. 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 #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 for

their 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 environmental

protection provided by vapor recovery system. They also offered recommended rule language for fueling of motor vehicles at gasoline

dispensing 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 Storage Tank 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’s

willingness to work with interested parties to find reasonable solutions to compliance problems. 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.

RESPONSE: The Missouri Department of Natural Resources’ Air

Pollution 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 storage 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 storage 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 amendment

and 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 storage

tanks (ASTs) larger than one thousand (1,000) gallons at gasoline

dispensing facilities. This would place a hardship on some businesses that currently have such tanks in use. They requested that

DNR “grandfather” all existing aboveground storage tanks, as doing

so 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 than

one 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 by

the 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 approval

of 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/vacuum

valve 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 are

often then forced into non-compliance with the department’s underground storage 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 of

volatile 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-eight

percent (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 concerns

of 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 storage 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 know

of 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 a

barrier 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 also

be 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 to

allow 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 rule

text 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 modifications 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 Rulemaking
new 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 gasoline

dispensing 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 or

other urgent situations, but believe the proposed language is needlessly complex. They requested eliminating paragraph (3)(G)4., as it

would be unnecessary if the department agrees to change the requirement from a permit to a notice when making repairs. They further

requested 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 and

proposed amendments should be eliminated or at the very least drastically reduced. They, however, 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. Louis

area 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 for

fueling 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 to

inspect 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 storage

tanks. In addition, facility compliance expectations are outlined in the

Department’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 do

not 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 at

completion 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. The

proposed 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 been

removed 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 Storage, Loading

and Transfer

(3) General Provisions.

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(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 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 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 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. 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 storage

tank system.

4. 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.

(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—

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.

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

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

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 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; 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 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 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 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; 

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.

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 tThis rRule 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 sStore 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 sStore 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 Sstationary 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. 

 (JB) 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 any 

petroleum 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 cm2

 per meter of tank diameter 

(1.0 in2

 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 Lloading 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 valuesEquipped 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)(DC) 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. 

 (GF) 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. 

 (JI) 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 H2O) 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)(JI)1. of this rule; and 

 3. Reporting and record keeping shall be per 

subsection (4)(FD) 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. 

 (DC) 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. 

 (FD) Owner/Operator Compliance. The owner or operator of a 

vapor recovery system subject to subsection (3)(JC), (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 directorTesting 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 an 
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. 

 (GD) 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.