Cssd Comparison Table 5.5.14

8/10/2019 Cssd Comparison Table 5.5.14

1/19

{J1838040.1}

CENTER FOR SUSTAINABLE SHALE DEVELOPMENTPERFORMANCE STANDARDS AND REGULATORY STANDARDS

ACROSS THE APPALACHIAN BASIN

This document is for general information purposes only and should not be construed as legal advice, legal opinion or any other advice on any specific facts or circumstances. The information in this document is subject to change without n

due to changed circumstances. You should not rely on this information or its applicability to any specific circumstance without first seeking professional advice. Use of the information does not create an attorney-client relationship betwe

the user and Eckert Seamans. Eckert Seamans and contributing authors expressly disclaim all liability to any person in respect of the consequences of anything done or omitted to be done wholly or partly in reliance upon the use or conten

this document.

If you have any questions, please contact Erin McDowell at 412.566.6070 or Jessica Sharrow at 412.566.5941

April 29, 2014


2/19

Center for Sustainable Shale DevelopmentPerformance Standards and Regulatory Standards Across the Appalachian Basin

WATER STANDARDS

{J1838040.1}

1

NO. CSSD PERFORMANCE STANDARD PENNSYLVANIA OHIO WEST VIRGINIA

1.1 Operators shall maintain zero discharge of wastewater(including drilling, flowback and produced waters) to Watersof the Commonwealth of Pennsylvania and other states until

such time as CSSD adopts a standard for treating shalewastewater to allow for safe discharge. Such standard will be

adopted by September 1, 2014. Note: This standard does notapply to nor prohibit disposal of wastewater by deep well

injection.

Operators must control and dispose of wastewater consistent

with Pennsylvanias Clean Streams Law/NPDES program.1

Except as provided in paragraph (3) (allowing discharge toPOTWS) there may be no discharge of wastewater into

waters of this Commonwealth from any source associatedwith fracturing, production, field exploration, drilling or well

completion of natural gas wells.2

Paragraph (3) requires that the discharge may not contain

more than 500 mg/L TDS, 250 mg/L total chlorides, 10mg/L total barium, 10 mg/L total strontium (monthly

average).

Note: By voluntary agreement with PA DEP, operators agreed to

no longer discharge wastewater to POTWs in Pennsylvania.

No person shall place or cause to be placed in ground

water or in or on the land or discharge or cause to bedischarged in surface water brine, crude oil, natural gas,or other fluids associated with the exploration,

development, well stimulation, production operations, orplugging of oil and gas resources that causes or could

reasonably be anticipated to cause damage or i njury to

public health or safety or the environment.3

Land application of brine is permitted.4

Operators may dispose of wastewater by underg

injection well, NPDES/POTWs, or re-use. Currland application of completion returns is prohib

2.1 Operators shall maintain a plan to recycle flowback andproduced water, for usage in drilling or fracturing a well, to

the maximum extent possible.

Recycling allowed; Operators must submit, prior to drilling,a source reduction strategy in connection with flowback andproduced waters, or prepare a waste stream characterization.6

Recycling allowed; Operators must submit as part of itsdrilling permit a plan for disposal of drilling wastewater.7

WV DEP strongly encourages operators to recyflowback and produced wastewater.8

Re-use of wastewater must be reported in watermanagement plan.9

2.2 By September 24, 2014 or date of an operators initialapplication for certification (whichever is later), Operators

must recycle a minimum of 90% of the flowback andproduced water, by volume, from its wells in all core

operating areas in which an Operator is a net water user.

No required recycling minimum. No required recycling minimum. No required recycling minimum.

2.3 CSSD will consider a recycling standard for a net waterproducer within one year. Operators will maximize the use of

recycled water to the extent possible during this time.

See 2.2 above. See 2.2 above. See 2.2 above.

3.1 Any new pits designed shall be double-lined and equippedwith leak detection.

Single-lined pits on the well pad permitted. 10 Pits on the well pad must be constructed and maintainedto prevent escape of brine.11

Single-lined pits on the well pad permitted. 12

3.2 Operators, by March 20, 2014 or initial date of application for

certification (whichever is later), shall contain drilling fluid,when using oil-containing drilling fluids to drill a well, in a

closed loop system at the well pad (e.g. no ground pits).

Ground pits permitted.13 Ground pits permitted.14 Ground pits permitted.15

3.3 Operators, by March 20, 2015 or initial date of application forcertification (whichever is later), shall contain drilling fluid

and flowback water in a closed loop system at the well pad,eliminating the use of pits for all wells.

Closed loop system not required, see 3.2 above. Closed loop system not required, see 3.2 above. Closed loop system not required, see 3.2 above.


3/19


WATER STANDARDS

{J1838040.1}

2


4.1 When utilizing centralized impoundments for the storage offlowback and/or produced waters, Operators shall ensure thatfree hydrocarbons are removed from the water prior to storage

and that new impoundments are double-lined with animpermeable material, equipped with leak detection and t ake

measures to reasonably prevent hazards to wildlife. Totalhydrocarbons should be substantially removed.

Impoundments must be double-lined and equipped with leak

detection (including upgradient and downgradientmonitoring wells).16

Ohio is currently drafting regulations governing

impoundments. Pits and impoundments holding >5,000 barrels o

wastewater must be designed to minimize adveenvironmental effects and to assure safety to thepublic.17

Impoundments must be double-lined and equipwith leak detection (including upgradient and

downgradient monitoring wells).18

4.2 Additionally, CSSD will facilitate research designed todetermine the extent of hydrocarbon emissions from thesewaters so that by September 1, 2014, a decision can be made

as to whether, and to what extent, t his standard should beamended.


5.1 Operators shall establish an Area of Review (AOR), prior todrilling a well, which encompasses both the vertical and

horizontal legs of the planned well. Within the AOR, theoperator must conduct a comprehensive characterization ofsubsurface geology, including a risk analysis, that

demonstrates the presence of an adequate confining layer(s)above the production zone that will prevent adverse migrationof hydraulic fracturing fluids. As part of the risk analysis,

and before proceeding with hydraulic fracturing, the operatormust also conduct a thorough investigation of any active orabandoned wellbores within such area of review or other

geologic vulnerabilities (e.g., faults) that penetrate theconfining layer and adequately address identified risks.

No Area of Review requirement.

Note: PA has proposed an area of review risk assessment fordrilling permits as part of new chapter 78 regulations.


Note: Ohio ODNR, as part of each permit application,performs a geological risk analysis and may require anoperator to plug or rebuild an abandoned well.


Note: Each well permit, with depth greater thanfeet must identify all wells within 2,400 feet of surface location of the new well and 500 feet of

horizontal section of the wellbore.19

6.1 Operators shall develop and implement a plan for monitoringexisting water sources, including aquifers and surface waterswithin a 2,500 foot radius of the wellhead (or greater distance,

if a need is clearly indicated by geologic characterization), anddemonstrate that water quality and chemistry measured during

a pre-drilling assessment are not impacted by operations.

Pre-drilling water survey may be completed by an operator

to avoid a presumption of liability for contamination of awater supply within 2,500 feet of the vertical wellbore.20

The operator must submit as part of its drilling permit the

results of sampling water wells within 1,500 feet of theproposed horizontal wellhead prior to commencement ofdrilling.21

Operators must sample and analyze water from

one known and existing well or spring within 1,feet of the proposed well. 22

6.2 Operators must conduct periodic monitoring for at least oneyear following completion of the well. Such monitoring must

be extended if results indicate potentially adverse impacts onwater quality or chemistry by operations.

No required post-completion water monitoring. No required post-completion water monitoring. No required post-completion water monitoring.

6.3 In the event that monitoring establishes a possible link

between an Operators activities and contamination of a watersource, the Operator shall develop and implement an

investigative plan and, if a positive link is established,implement a corrective action plan.

PA DEP may issue orders necessary to aid in enforcement ofstatutory, regulatory and permit r equirements.23

Ohio DNR shall enforce this chapter and the rules, termsand conditions of permits and registration certificates, and

orders adopted or issued pursuant thereto. 24

WV DEP is responsible for enforcing offenses tarticle 6 (oil and gas) or any permit issued pursu

this article.25

6.4 The testing and monitoring plan should provide for additionalmonitoring in the event a well is re-stimulated.



4/19


WATER STANDARDS

{J1838040.1}

3


7.1 Operators shall design and install casing and cement tocompletely isolate the well and all drilling and produced fluidsfrom surface waters and aquifers, to preserve the geologic seal

that separates fracture network development from aquifers,and prevent vertical movement of fluids in the annulus.

String(s) of casing shall be run and permanently cemented to

prevent migration of gas or fluids into sources of freshgroundwater.26

A well shall be constructed using sufficient steel or

conductor casing in a manner that supports unconsolidatedsediments, that protects and isolates all undergroundsources of drinking water, as identified by ODNR, and

that provides a base for a blowout preventer or other wellcontrol equipment that is necessary to control formation

pressures and fluids during the drilling of the well and

other operations to complete the well.27

Case and cement horizontal wells to prevent the

migration of gas and other fluids into the freshground-water and coal seams, and prevent polluof or diminution of fr esh groundwater; installati

and use of blow out preventer and other well coequipment.28

7.2 Operators will not use diesel fuel in their hydraulic fracturing

fluids.29

No prohibition on diesel (see endnote 44). Diesel is permitted below cemented surface casing (see

endnote 44).30

No prohibition on diesel (see endnote 44).

7.3 Operators will publically disclose the chemical constituentsintentionally used in well stimulation fluids. Disclosures willinclude: information identifying the well, the operator and the

dates of the well stimulation; the t ype and total volume of thebase fluid; the type and amount of any proppant; all chemical

additive products used in a well stimulation, including thename under which the product is marketed or sold, the vendor,and a descriptor of additive's purpose or purposes (e.g.

biocide, breaker, corrosion inhibitor, etc.); the common nameand Chemical Abstracts Service registry number for each

chemical ingredient used in a stimulation fluid; the actual ormaximum concentration of each chemical ingredient,

expressed as a percent by mass of the total stimulation fluid.

Chemical ingredients should be disclosed in a manner thatdoes not link them to their respective chemical additiveproducts. Disclosure of the above information will be offered

to the relevant state agency and will also be posted onFracFocus.org. If an operator, service company or vendorclaims that the identity of a chemical ingredient is entitled to

trade secret protection, the operator will include in itsdisclosures a notation that trade secret protection has been

asserted and will instead disclose the relevant chemical familyname. Operators will implement measures consistent with

state law to assist medical professionals in quickly obtainingtrade secret information from the operator, service companyor vendor holding the trade secret that may be needed for

clinical diagnosis or treatment purposes.

Operators must submit well completion reports to PA DEPand a chemical disclosure form to Frac Focus with thefollowing: (i) A descriptive list of the chemical additives in

the stimulation fluids, including any acid, biocide, breaker,brine, corrosion inhibitor, crosslinker, demulsifier, frictionreducer, gel, iron control, oxygen scavenger, PH adjusting

agent, proppant, scale inhibitor and surfactant. (ii) The tradename, vendor and a brief descriptor of the intended use orfunction of each chemical additive in the stimulation fluid.

(iii) A l ist of the chemicals intentionally added to thestimulation fluid, by name and chemical abstract service

number. (iv) The maximum concentration, in percent bymass, of each chemical intentionally added to the stimulation

fluid. (v) The total volume of the base fluid. (vi) A list ofwater sources used under the approved water managementplan and the volume of water used. (vii) The pump rates and

pressure used in the well. (viii) The total volume of recycledwater used.31

Trade secret protection available; chemicals covered by tradesecret protections must be provided to medical professional

upon execution of a confidentiality agreement.32

Operators must submit to the Ohio DNR or Frac Focus thefollowing: (a) If applicable, the t rade name and the totalamount of all products, fluids, and substances, and the

supplier of each product, fluid, or substance, not includingcement and its constituents and lost circulation materials,intentionally added to facilitate the drilling of any portion

of the well until the surface casing is set and properlysealed. The owner shall identify each additive used andprovide a brief description of the purpose for which the

additive is used. In addition, the owner shall include a listof all chemicals, not including any information that is

designed as a trade secret pursuant to division (I)(1) ofthis section, intentionally added to all products, fluids, or

substances and include each chemicals correspondingchemical abstracts service number and the maximumconcentration of each chemical. The owner shall obtain

the chemical information, not including any informationthat is designated as a trade secret pursuant to division(I)(1) of this section, from the company that drilled thewell, provided service at the well, or supplied the

chemicals. If the company that drilled the well, providedservice at the well, or supplied the chemicals provides

incomplete or inaccurate chemical information, the ownershall make reasonable efforts to obtain the requiredinformation from the company or supplier. (b) For

purposes of division (A)(9)(a) of this section, if recycledfluid was used, the total volume of recycled fluid and the

well that is the source of the recycled fluid or thecentralized facility that is the source of the recycled

fluid.33

Operators must submit to WV DEP and Frac Fthe following: The additives used in the hydraulfracturing or stimulation process, including each

additives specifictrade name, supplier, and purThe operator shall also list the chemical componof each additive, along with each chemicals CA

registry number, its maximum concentration in additive, and its maximum concentration in thefracturing fluid, including the carrier (base) flui

the volume of the carrier fl uid used. Theconcentrations shall be expressed as a mass perc

The operator or service provider may designate information regarding chemical components as

confidential trade secrets not to be disclosed by agency to the general public, but the operator orservice provider shall provide that information u

request to a health care professional in a medicaemergency or for diagnostic or treatment purpo

7.3

7.4 CSSD will develop a standard relating to the public disclosureof chemicals other than well stimulation fluids by September1, 2013.

No requirement. No requirement. No requirement.


5/19


WATER STANDARDS

{J1838040.1}

4


7.5 Operators will also work toward use of more environmentallyneutral additives for hydraulic fracturing fluid.

Operators must prepare and submit a waste stream source

reduction strategy report.35

No requirement. No requirement.

7.6 Mechanical integrity tests shall be performed when

refracturing an existing well. Operators must conduct quarterly inspections of wells to

ensure compliance with well construction and operating

requirements. 36

Well pressure testing requirements.37 Casing must possess an internal pressure rating greater than the anticipated maximum pressure.

8.1 Operators shall design each well pad to minimize the risk thatdrilling related fluids and wastes come in contact with surface

waters and fresh groundwater.

Unconventional well sites must be designed and constructed

to prevent spills to the ground surface or spills off the wellsite.39

Operators must utilize best management practices in well

site construction.40

Note: Ohio has proposed more detailed rules in

connection with well pad construction which will requireengineer certified plans and Ohio DNR oversight.

Operators must implement erosion and sedimen

control plans and site construction plans in welldevelopment.41

Operators must prevent surface and undergrounwater pollution.42

8.2 In preparation for any spill or release event, Operators shall

prior to commencement of drilling, develop and implement anemergency response plan, ensure local responders haveappropriate training in the event of an emergency, and work

with the local governing body, in which the well is located, toverify that local responders have appropriate equipment to

respond to an emergency at a well.

Operators must develop and implement an emergency

response plan for each well site that provides for equipment,procedures, training and documentation to properly respondto emergencies.43

Signage and security measures at well site required.44 Safety plan must accompany each drilling perm

detail weekly training sessions, location of schoand public buildings within 1 mile radius of theand maintain plan to notify affected residents ofemergency event and provide to local emergenc

responders.45

8.3 In addition, in the event of spill or release, beyond the well

pad, operators shall immediately provide notification to thelocal governing body and any affected landowner.

Operators must immediately notify PA DEP of a spill anddownstream users of water.46

Operator must provide Ohio EPA verbal notificationwithin 30 minutes of knowledge of the release unlessnotification within that time frame i s impractical due to

uncertain circumstances.

47

Operators must immediately notify WV DEP ofspill.48


6/19


AIR STANDARDS

{J1838040.1}

5

NO. CSSD PERFORMANCE STANDARD FEDERAL49 PENNSYLVANIA50 OHIO51 WEST VIRGINIA52

9 Reduced Emissions Completions (REC)

Beginning on 1/1/14direct allpipeline-quality gas during completion

of development wells and re-completion

or workover of any well into a pipelinefor sales.

No venting allowedmust be flared inaccordance with CSSD PerformanceStandard No. 10.

Acceptable reasons for flaringlowcontent of flammable gas and safetyreasons.

Unacceptable reasons for flaringi)

lack of pipeline connection except forexploratory or extension wells; ii)

inadequate water disposal capacity; iii)inadequate or lack of flowbackequipment or operating personnel.

NSPS Subpart OOOO

Beginning 10/15/12:

Must capture and direct fl owback

emissions to a completion combustiondevice, except in conditions that mayresult in a fire hazard or explosion.53

Beginning 1/1/15:

REC equipment required for all wellsbesides those classified as wildcat,delineation or low pressure.54

Salable quality gas must be routed to the

gas flow line as soon as practicable.55

Emissions that cannot be directed to thegas flow must be directed to a completion

combustion device (e.g., flare) with acontinuous ignition source except inconditions that may result in a fire hazard

or explosion.56

General duty to safely maximize resource

recovery and minimize releases to theatmosphere during flowback andsubsequent recovery.57

Exemption Category No. 3858

Well drilling, completion and work-over activitiesare exempted from permitting requirements.59

No state-specific REC requirements inaddition to NSPS Subpart OOOO.

Open flaring is only allowed under the followingcircumstances:

Flaring used at exploration wells to determinewhether oil and/or gas exists in geologicalformations or to appraise the physical extent,reserves and likely production rate of an oil or

gas field.

Flaring used for repair, maintenance,

emergency or safety purposes.

Flaring used for other operations at a wellheador facility to comply with 40 CFR Part 60,Subpart OOOO requirements.

Current

No state-specific REC requirements inaddition to NSPS Subpart OOOO.

Flaring required except for gas releases by aproperly functioning relief device and gasreleased by controlled venting for testing,

blowing down and cleaning out wells.60

Proposed

Natural Gas Completion Permit-by-Rule61

requires compliance with NSPS SubpartOOOO.

No state-specific REC requirements in

addition to NSPS Subpart OOOO

Compliance with NSPS Subpart OOOrequirements is required by General P

G70-A62

; (however, permit is not reqube obtained prior to well completionactivities.)63


7/19


AIR STANDARDS

{J1838040.1}

6

NO. CSSD PERFORMANCE STANDARD FEDERAL49 PENNSYLVANIA50 OHIO51 WEST VIRGINIA52

10 Flaring During Well Completions, Re-Completions, Workovers

When flaring is permitted during wellcompletion, re-completions or

workovers of any well (pursuant toStandard No. 9) meet the following

requirements:

Raised/elevated flares or engineered

combustion device with a reliablecontinuous ignition source.

98% destruction efficiency.

Development well: flaring no more

than 14-days (for life of well).

Exploratory/Extension wells: flaringno more than 30-days (for life of

well).

No visible emissions from flaresexcept for periods not to exceed atotal of five minutes during any t wo

consecutive hours.

NSPS Subpart OOOO

Completion combustion devices (e.g.flares)

are required to have a continuous ignitionsource.64


Open flaring during completions requires

compliance with NSPS Subpart OOOO.

Post-Completion Requirements

Enclosed flare (Raised/elevated flares or

engineered combustion device) must be used forpermanent installations.

All permanent enclosed flaring operations mustbe designed and operated in accordance with the

requirements of 40 CFR 60.18.

Open Flaring is only allowed under the following

circumstances:

Flaring used at exploration wells to determine

whether oil and/or gas exists in geologicalformations or to appraise the physical extent,reserves and likely production rate of an oil orgas field.

Flaring used for repair, maintenance,emergency or safety purposes.

Flaring used for other operations at a wellhead

or facility to comply with 40 CFR Part 60,

Subpart OOOO requirements.

Other Requirements

Opacity is limited to 20% or greater for an

aggregated 3 minute period in any 1 hour, butcannot be equal to or greater than 60% opacity atany time.66

Current

Requires properly functioning relief

device.67

Proposed Natural Gas Completion Permit-by-

Rule68

Emissions limitations for completionoperations:

34 tons/yr VOCs.

1.7 tons/yr NOx.

9.3 tons/yr CO.

0.82 tons/yr HAP.

Temporary flaring allowed for 30-dbefore a permit is required.69

20% opacity limitation and PM

emissions limit set according to aformula70

General Permit G70A: 20% opacity

limitation and PM emissions limit setaccording to a formula.71

However, permit is not required to

obtained prior to well completionactivities.72


8/19


AIR STANDARDS

{J1838040.1}

7

NO. CSSD PERFORMANCE STANDARD FEDERAL PENNSYLVANIA OHIO WEST VIRGINIA

11.1 Diesel Non-road Drilling Rig Engines

Meet EPA Tier 2 standards by March 20, 2013.

25% of owner/operator engine utilization ( hp) meeting

EPA Tier 4 standards for PM by March 20, 2015.


EPA Tier 4 standards for PM by September 24, 2015.

95% of owner/operator engine utilization meeting EPA

Tier 4 standards for PM by September 24, 2016.

Use ultra-low sulfur diesel (15 ppm of sulfur) at all times.

U.S. EPA regulates emissions from non-road dieselengines according to varying tiered levels based

on the engines manufacturing date.73

Starting in 2010, diesel produced for use in non-roadengines required to meet ultra-low sulfur (15 ppm of

sulfur) requirement.74

Only ultra-low sulfur diesel fuel will be available.

Non-road engines are exempt frompermitting requirements under

Exemption Category No. 38.75

Non-road engines exempt frompermitting requirements provided

engines meet 20% opacity limitation.76

Non-road engines are exempt fpermitting requirements.77

11.2(a) Diesel Non-road Fracturing Pump Engines

Meet EPA Tier 2 standards by March 20, 2014.

25% of owner/operator engine utilization ( hp) meetingEPA Tier 4 standards for PM by September 24, 2015.


EPA Tier 4 standards for PM by September 24, 2016.95%of owner/operator engine utilization meeting EPA Tier 4standards for PM by September 24, 2017.


U.S. EPA regulates emissions from non-road dieselengines according to varying tiered levels based

on the engines manufacturing date78

Starting in 2010, diesel produced for use in non-roadengines required to meet ultra-low sulfur (15 ppm of

sulfur) requirement.79


Non-road engines are exempt frompermitting requirements under

Exemption Category No. 38.80

Non-road engines exempt frompermitting requirements provided

engines meet 20% opacity limitation.81

Non-road engines are exempt fpermitting requirements.82

11.2(b) Diesel Heavy-Duty Vehicle Fracturing Pump Engines

50% of engines meeting EPA 2007 and Later Model Year

Highway Heavy-Duty Vehicles and Engines emissionsstandards for PM by March 20, 2013.

80% of engines meeting EPA 2007 and Later Model Year

Highway Heavy-Duty Vehicles and Engines emissionsstandards for PM by September 24, 2017.


U.S. EPA regulates engine emissions from highwayheavy-duty vehicles based on the vehicles modelyear.83

Starting in 2006, highway diesel fuel required tomeet ultra-low sulfur (15 ppm of sulfur)

requirement.84


Preempted.85 Preempted.86 Preempted.87


9/19


AIR STANDARDS

{J1838040.1}

8


12.1 Existing Compressor Engines

By March 20, 20141.5

g/hp-hr NOx emissionlimitation for existing

compressor engines greaterthan 100 hp.

NSPS Subpart JJJJ (Standards ofPerformance for Stationary Spark Ignition

Internal Combustion Engines)

Applies to constructed, reconstructed,

and modified engines after June 12,2006.88

Emissions limitations for enginesmanufactured between 2007/2008 and

2010/2011 greater than 100 hp:89

2.0 g/hp-hr for NOx.

4.0 g/hp-hr for CO.

1.0 g/hp-hr for VOCs.

Compressor engines are also subject to theNational Emission Standards for HazardousAir Pollutants (NESHAP) for Stationary

Reciprocating Internal Combustion Engines(RICE) at 40 CFR. 63, Subpart ZZZZ (i.e.,the RICE MACT)90

Previous Exemption Category No. 38

Existing compressor engines (those

installed prior to August 10, 2013)exempt from any permitting or emission

limitation requirements if less than 100hp.

Previous GP-5

Prior to February 2013 - compressor

engines greater than or equal to 100 hpand less than 1500 hp were subject to the

previous GP-5 emissions limitations:

2.0 g/hp-hr NOx.

2.0 g/hp-hr CO.

2.0 g/hp-hr VOCs.

Previous Oil and Gas Well-Site Production Operations, General Permit12

Engines must comply with NSPS Subpart JJJJ standards.91

Specific emissions limitations:92

20% opacity, 6-min average.

Particulate Emissions (PE):

0.310 lb/MMBtu for engines 600 hp.

0.062 lb/MMBtu for engines > 600 hp.

2.6 tons of SO2/year.

Total combined engine power less than or equal to 1,300 hp: 93

2.0 g/hp-hr NOx or 160 ppmvd at 15% O2 for engines 100hp.

4.0 g/hp-hr CO or 540 ppmvd at 15% O2 for engines 100hp.

1.0 g/hp-hr VOCs or 86 ppmvd at 15% O2 for engines 100

hp.

Total combined engine power greater than 1,300 hp:

1.0 g/hp-hr NOx /or 82 ppmvd at 15% O2 for engines 100

hp.

2.0 g/hp-hr CO/or 270 ppmvd at 15% O2 for engines 100

hp.

0.7 g/hp-hr VOCs or 60 ppmvd at 15% O2 for engines 100 hp.

Natural Gas Compressor Station General Number G33-A94

Engines over 100 HP - compliance wiNSPS Subpart JJJJ.


10/19


AIR STANDARDS

{J1838040.1}

9


12.2 New Lean-Burn CompressorEngines

Emissions limitations for new,purchased, replacement,

reconstructed, or relocatedlean-burn engines greater than

100 hp: 0.5 g/hp-hr NOx.

2.0 g/hp-hr CO.

0.7 g/hp-hr VOCs.

NSPS Subpart JJJJ (Standards ofPerformance for Stationary Spark

Ignition Internal CombustionEngines)

Emissions limitations forengines manufactured on or

after 2010/2011 greater than100 hp engine models(depending on engine size)95:


2.0 g/hp-hr for CO.

0.7 g/hp-hr for VOCs.

Compressor engines are alsosubject to the National Emission

Standards for Hazardous AirPollutants (NESHAP) for

Stationary Reciprocating InternalCombustion Engines (RICE) at40 CFR. 63, Subpart ZZZZ ( i.e.,

the RICE MACT)96

Exemption Category No. 38 (CompressorEngines at the Wellpad)97

Compressor engines are the wellpad (thoseinstalled on or after August 10, 2013) areexempt from permitting requirements under

Exemption Category No. 38 provided that:

NOx emissions from stationary internalcombustion engines at the wells, and

wellheads are less than 100 lbs/hr, 1000lbs/day, 2.75 tons per ozone season (May

1 to September 30), and 6.6 t ons per yearon a 12-month rolling basis.

Combined VOC emissions from all thesources at the facility are less than 2.7

tons on a 12-month rolling basis.Additionally, combined HAP emissions

at the facility must be less than 1000 lbsof a single HAP or one ton of acombination of HAPs in any consecutive

12-month period. If the VOCs emissionsinclude HAPs, this HAP exemptioncriteria is met.98

GP-5 (Compressor Engines at Natural Gas

Compression and/or Processing Facilities) (Feb.2013)

The facility emissions are limited to non-

major emission thresholds. (SyntheticMinor).99

Natural gas fired lean burn less than 100hp100


2.0 g/hp-hr for CO

Natural gas lean burn greater than 100 hpand less than or equal to 500 hp101


2.0 g/hp-hr for CO.

0.7 g/hp-hr for non- methane/non-ethanehydrocarbons (except formaldehyde).

Natural gas lean burn greater than 500 hp102

0.5 g/hp-hr for NOx. 93% reduction for CO.

0.25 g/hp-hr for non-methane/non-ethanehydrocarbons (except formaldehyde).

0.05 g/hp-hr for formaldehyde.

Ohio Oil and Gas Production Operations, General Permit 12.1

Applicable for facilities that have less than or equal to 1,800 hp total for all natural gas engines and

where the flare system is operated at a heat input capacity less than or equal to 10 MMBtu/hr.103


Stack Height:105

Engine 250 hp: exhaust stack at least 20' above ground level.

Engine < 250 hp: exhaust stack at least 12' above ground level.

Specific Emission Limitations106





Engines exempt from SO2 emission limitation during for any day in which only natural gas isburned pursuant to OAC 3745-18-06(A).


2.0 g/hp-hr NOx for engines over 100 hp.

4.0 g/hp-hr CO for engines over 100 hp.

1.0 g/hp-hr VOC for engines over 100 hp.





5.75 lbs NOx/hr from all spark ignition engines combined.


Applicable for facilities that have less than or equal to 1,000 hp total for all natural gas engines andwhere the flare system is operated at a heat input capacity less than or equal to 32 MMBtu/hr.108


Stack Height:110








Engines exempt from SO2 emission limitation during for any day in which only natural gas isburned pursuant to OAC 3745-18-06(A).

Total combined engine power less than or equal to 500 hp:




Total combined engine power greater than 500 hp:112





Natural Gas ProductiFacility Class II Gen

Permit G70-A

Requires complia

with NSPS SubpaJJJJ.113


11/19


AIR STANDARDS

{J1838040.1}

10

NO. CSSD PERFORMANCE STANDARD FEDERAL PENNSYLVANIA OHIO WEST VIRGIN

12.3 New Rich-Burn CompressorEngines

Emissions limitations for new,purchased, replacement,

reconstructed, or relocated rich-burn engines greater than 100 hp:

0.3 g/hp-hr NOx.

2.0 g/hp-hr CO.

0.7 g/hp-hr VOCSs.

NSPS Subpart JJJJ(Standards of Performance

for Stationary SparkIgnition Internal

Combustion Engines)

Emissions limitations

for enginesmanufactured on or after2010/2011 greater than100 hp engine models

(depending on enginesize):114


2.0 g/hp-hr for CO.

0.7 g/hp-hr forVOCs.

Compressor engines arealso subject to the NationalEmission Standards for

Hazardous Air Pollutants(NESHAP) for StationaryReciprocating Internal

Combustion Engines

(RICE) at 40 CFR 63,Subpart ZZZZ (i.e., the

RICE MACT)115

Exemption Category No. 38 (Compressor Enginesat the Wellpad)116

Compressor engines are the wellpad (thoseinstalled on or after August 10, 2013) exempt

from permitting where:

NOx emissions from stationary internal

combustion engines at the wells, andwellheads are less than 100 lbs/hr, 1000

lbs/day, 2.75 tons per ozone season (May 1to September 30), and 6.6 tons per year on a

12-month rolling basis.

Combined VOC emissions from all the

sources at the facility are less than 2.7 tonson a 12-month rolling basis. Additionally,

combined HAP emissions at the facilitymust be less than 1000 lbs of a single HAP

or one ton of a combination of HAPs in anyconsecutive 12-month period. If the VOCsemissions include HAPs, this HAP

exemption criteria is met.117

Coverage under GP-5 (Compressor Engines at

Natural Gas Compression and/or ProcessingFacilities) (Feb. 2013)

The facility emissions are limited to non-majoremission thresholds. (Synthetic Minor).118

Natural gas fired rich burn less than 100 hp:119

2.0 g/hp-hr NOx.

2.0 g/hp-hr CO.

Natural gas rich burn greater than 100 hp andless than or equal to 500 hp: 120

0.25 g/hp-hr NOx.

0.30 g/hp-hr CO;


Natural gas rich burn greater than 500 hp:121

0.20 g/hp-hr NOx.

0.30 g/hp-hr CO.


76% reduction for formaldehyde.


Applicable for facilities that have less than or equal to 1,800 hp total for all natural gas engines and where the flare

system is operated at a heat input capacity less than or equal to 10 MMBtu/hr. 122


Stack Height:124


Engine < 250 hp: exhaust stack at least 12' above ground level. Specific Emission Limitations125





Engines exempt from SO2emission limitation during for any day in which only natural gas is burned pursuantto OAC 3745-18-06(A).









5.75 lbs NOx/hr from all spark ignition. engines combined.

Ohio Oil and Gas Production Operations, General Permit 12.2Applicable for facilities that have less than or equal to 1,000 hp total for all natural gas engines and where the flaresystem is operated at a heat input capacity less than or equal to 32 MMBtu/hr.127


Stack Height:129








Engines exempt from SO2 emission limitation during for any day in which only natural gas is burned pursuant

to OAC 3745-18-06(A).

Total combined engine power less than or equal to 500 hp:



1.0 g/hp-hr VOC for engines over 100 hp. Total combined engine power greater than 500 hp:131





Natural GasProduction F

Class II GenePermit G70-A

Compliance wNSPS Subpa


12/19


AIR STANDARDS

{J1838040.1}

11


13 Storage Vessels

By October 15, 2013all

existing and new individualstorage vessels at the wellpad

with VOC emissions equal toor greater than 6 tpy must

install controls to achieve atleast a 95% reduction inVOC emissions.

NSPS Subpart OOOO

New Group 1 storage vessels (constructed,modified, or reconstructed after August 23, 2011

and before April 12, 2013) that have potentialVOC emissions equal to or greater than 6 tonsper year (tpy) - at least a 95% reduction in VOC

emissions by April 15, 2015.133

New Group 2 storage vessels (constructed,

modified, or reconstructed after April 12, 2013)that have potential VOC emissions equal to orgreater than 6 tons per year (tpy) - at least a 95%reduction in VOC emissions by April 15, 2014 or

within 60-days of startup (whichever is later). 134

6 tpy VOC determination may take into

account enforceable limits in an operatingpermit or other requirement establishedunder a Federal, State, local or tri balauthority.135

Emissions from a storage vessel that arerecovered and routed to a process through a

vapor recovery unit (VRU) can be excludedfrom the 6 tpy VOC determination providedcertain requirements are met.136

Control devices (installed to achieve the 95%

reduction in VOC emissions discussed above)may be removed if emissions from the storage

vessel have been below 4 tpy on an uncontrolledbasis for 12 consecutive months.137

Control device must be reinstalled: (1) if awell feeding the storage vessel undergoes

fracturing or refracturing; or (2) the monthlyemissions from the uncontrolled storage

vessel increase to 4 tpy or greater.138


Storage vessels/storage tanks are

exempt from permit requirements ifthey are equipped with VOC emission

controls achieving emission reductionof 95% or greater.

Storage tanks can qualify for theexemption if combined VOC

emissions from all the sources at thefacility are less than 2.7 tons on a 12-

month rolling basis. Combined HAPemissions at the facility must be lessthan 1000 lbs of a single HAP or one

ton of a combination of HAPs in anyconsecutive 12-month period in order

to qualify for the exemption. If theVOCs emissions include HAPs, thisHAP exemption criteria is met.140

No de minimis emission threshold per

tank as allowed in NSPS SubpartOOOO (i.e., must reduce storage

tank/storage vessel VOC emissions by95% if combined VOC emissionsfrom storage vessels/storage tanks are

above 2.7 tpy in order to qualify forexemption).

Oil and Gas Well-Site Production Operations, General Permit 12.1 and 12.2 141142

Requires compliance with NSPS Subpart OOOO where applicable

Designed minimum control efficiency of 95% for an enclosed flare/combustor (where

used for compliance with NSPS Subpart OOOO requirements, where applicable).

Flare/ combustion device may not operate at more than 10 MMBtu/hr (for General Permit

12.1) or 32 MMBtu/hr heat input (for General Permit 12.2), except: when a malfunction occurs (e.g., when excess gas must be safely disposed of by

venting it to the flare/combustion device); or

for repair pressure blow-downs; or

when another well is being drilled or fractured and the gas must be safely disposed of

by venting it to the flare/combustion device.

If required to install controls per the Subpart OOOO storage vessel requirements, an

enclosed combustion device must be operated with no visible emissions except for periodsnot to exceed a total of 1 minute in any 15 minute period, conducting Method 22 once

every calendar month.

Emission Limits for flare/combustion device in GP 12.1:

CO: 1.35 tons/month (12-month rolling period).

NOx: 0.25 tons/month (12-month rolling period).

SO2: 0.15 tons/month (12-month rolling period).

Emission Limits for flare/combustion device in GP 12.2:

CO: 4.32 tons/month (12-month rolling period).

NOx: 0.79 tons/month (12-month rolling period).

SO2: 0.48 tons/month (12-month rolling period).

Natural Gas ProductiClass II General Perm

Requires compliNSPS Subpart O


13/19


AIR STANDARDS

{J1838040.1}

12


14.1 Rod Packing at ReciprocatingCompressors

Change rod packing at allreciprocating compressors (both

existing and new), including those atthe wellhead, either every 26,000hours of operation or after 36 months.

NSPS Subpart OOOO

New reciprocating compressors (those installed after August

23, 2011)change rod packing either every 26,000 hours ofoperation or every 36 months as well as new reciprocating

compressors.144

Reciprocating compressors located at a well site or an adjacent

well site and servicing more than one well site are excludedfrom this requirement.145

No additional state-specific requirementsother than the requirements in NSPS Subpart

OOOO.

No additional state-specific requirements other than therequirements in NSPS Subpart OOOO.

No additional starequirements othe

requirements in NSubpart OOOO.

14.2 Pneumatic Controllers

By October 15, 2013, pneumaticcontrollers (both existing and new):

Lowbleed, with a natural gas

bleed rate limit of 6.0 scfh or less.

Zero bleed when electricity (3-phase electrical power) is on-site.

NSPS Subpart OOOO

New pneumatic controllers (those constructed (installed),modified or reconstructed on or after October 15, 2013) located

between the wellhead and a natural gas processing plant: bleedrate of 6.0 scfh or less.146

Exception to 6.0 scfh bleed ratewhere use of a greater bleed

rate is required based on functional needs, including responsetime, safety and positive actuation.147

GP-5 - Natural Gas Compression and/orProcessing Facilities

Lists pneumatic controllers as a covered

device, however, it contains no state-specificrequirements for such controllers additionalstate-specific requirements for such

controllers other than the requirements inNSPS Subpart OOOO.148

Ohio Oil and Gas Production Operations, General Permit 12.1 and12.2, specifically require compliance with Subpart OOOOrequirements for pneumatic controllers. 149

Natural Gas ProductiClass II General Perm

Requires complia

NSPS Subpart Orequirements for pcontrollers.150

14.3 Centrifugal Compressors New centrifugal compressors may not

contain wet oil seals.

Replace worn out wet seals on

existing centrifugal compressors withdry seals.

NSPS Subpart OOOO For centrifugal compressors installed after August 23, 2011 -

must reduce VOC emissions from each centrifugal compressorwet seal fluid degassing system by 95 % or greater.151

If a control device is used to reduce emissions, must equipthe wet seal fluid degassing system with a cover that meets

the requirements of 40 CFR 60.5411(b), that is connectedthrough a closed vent system that meets the requirements of

40 CFR 60.5411(a) and routed to a control device thatmeets the conditions specified in 40 CFR 60.5412(a), (b)and (c). As an alternative to routing the closed vent system

to a control device, may route the closed vent system to aprocess.

Not applicable to centrifugal compressors located at a well site

or at an adjacent well site and servicing more than one wellsite.152

GP-5 - Natural Gas Compression and/orProcessing Facilities

Compliance with NSPS Subpart OOOOrequirements for centrifugal compressors.153

No state-specific requirements in addition to NSPS SubpartOOOO requirements.

No state-specificrequirements in aNSPS Subpart Orequirements.


14/19


AIR STANDARDS

{J1838040.1}

13


14.4 Directed Inspection andMaintenance Program

By March 20, 2014 implement a directed

inspection and maintenanceprogram (DI&M) forequipment leaks from all

existing and new valves,pump seals, flanges,compressor seals, pressure

relief valves, open-endedlines, tanks and other processand operation components

that result in fugitiveemissions.

Monitored by a weekly

visual, auditory, andolfactory check.

Yearly mechanical or

instrument check to detectleaks.

Repair detected significant

leaks in a timely manner.

NSPS Subpart OOOO

Cover and closed vent inspections for new

storage vessels with potential to emit VOCemissions equal to or greater than 6 tpy. 154

Monthly olfactory, visual and auditory

inspections for defects that could result in air

emissions.

If leak detected: Within 5 daysmake first

repair attempt.

Complete repair within 30 days.

Apply grease to deteriorating or crackedgaskets to improve the seal while awaitingrepair.

Delay permissible if repair requiresshutdown or if emissions during repair

would be greater than delay of repair untilshutdown.


Perform a leak detection and repair (LDAR)

program inspection within 60 days after the wellis put into production and an annual inspection

thereafter.

Use of optical gas imaging camera (such as

FLIR), gas leak detector, or other leakdetection monitoring devices approved by

PADEP. Conduct on valves, flanges,connectors, storage vessels/storage tanks, and

compressor seals in natural gas orhydrocarbon liquids service

If leak is discoveredrepair within in 15days unless facility shutdown is required or

ordering replacement parts are necessary forthe repair.

Upon written requesting documentingjustificationPADEP may grant extension for

leak detection deadlines or repairs.

For storage vessels, leak detection and repair is to

be performed in accordance with NSPS SubpartOOOO.

A leak is considered repaired if one of thefollowing can be demonstrated:

No detectable emissions consistent with EPAMethod 21 specified in 40 CFR Part 60,Appendix A.A concentration of 2.5%

methane or less using a gas leak detector anda VOC concentration of 500 ppm or less.

No visible leak image when using an optical

gas imaging camera.

No bubbling at leak interface using a soapsolution bubble test specified in EPA Method21.

Any other method approved in writing by

PADEP.

Ohio Oil and Gas Production Operations, General Permit 12.1 and 12.1 156

Leak detection and repair program for ancillary equipment covered by permits,

including each pump, compressor, pressure relief device, connector, valve,flange, vent, cover, any bypass in the closed vent system, and each storage

vessel.

Leak detection/repair program requirements:

Use of FLIR camera or an analyzer meeting U.S. EPA Method 21 of 40 CFRPart 60, Appendix A.

Initial monitoring must be completed within 90 days of startup and quarterly

thereafter for a period of four consecutive quarters (1 year).

If following initial four consecutive quarters 2% of ancillary equipmenthave leaked during most recent quarterly monitoring event, then monitoringfrequency can be reduced to semi-annual.

If following two consecutive semi-annual periods 2% of ancillary

equipment have leaked during most recent semi-annual monitoring event,then monitoring frequency can be r educed to annual.

If 2% of the ancillary equipment have leaked during any one of the semi-annual or annual monitoring events, then monitoring frequency must be

returned to quarterly.

First repair attempt within 5 calendar days of determining a leak.

Repair must be made within 30 calendar days after leak detected.

References Subpart OOOO requirements (40 CFR 60.5416(c)(5)) forpermissible delay of repair (delay permissible if repair requires shutdown orif emissions during repair would be greater than delay of repair until

shutdown). Incorporates certain Subpart OOOO leak detection and r epair requirements

for cover and closed vent systems for "new" storage vessels with potential to

emit VOC emissions equal to or greater than 6 tpy at 40 CFR 60.5416(c)(4)and 40 CFR 60.5416(c)(5), including 5-day initial repair attempt, 30 dayrepair timeframe and permissible delay of repair.

Determination of Leak - Component leaking where instrument reading is equal

to or greater than:

pressure relief device in gas/vapor service: 10,000 ppm.

pressure relief device in light liquid service: 10,000 ppm.

pumps in light liquid service: 10,000 ppm.

compressor: 500 ppm.

sampling connection system (must be equipped with a closed-purge, closed-

loop, or closed-vent system) .

open ended valves or lines (must be equipped with a cap, blind flange, plug,

or a second valve.

valves in gas/vapor and light liquid service: 10,000 ppm.

closed vent system: 500 ppm.

connectors: 10,000 ppm. all other ancillary and associated equipment in VOC service: 10,000 ppm.

Emission Limitation for Fugitive Equipment Leaks - 10.56 tpy for VOCs.

G70-A

Compliance with

Subpart OOOO inrequirements for

vessels.157


15/19


AIR STANDARDS

{J1838040.1}

14


14.5 Well-bore freeze-up emissions

Eliminate VOC emissions associated with the prevention of

well-bore freeze-up (only de minimis emissions are permitted).

None. If facility-wide VOC emissions exceed 2.7tpy, Exemption Category No. 38 is not

applicable and Plan Approval (case-by-caseBAT) may be required.158

None. None.

14.6 Blowdown emissions

Existing and new compressors are required to be pressurized

when they are off-line for operational reasons in order t oreduce blowdown emissions.

None. If facility-wide VOC emissions exceed 2.7tpy, Exemption Category No. 38 is not

applicable and Plan Approval (case-by-caseBAT) may be required.159

None. None.

15.1

15.2

Truck Emission Requirements

By March 20, 2014 - 80% of all trucks used to tr ansport fresh

water or well flowback water must meet U.S. EPAs FinalEmission Standards for 2007 and Later Model Year Highway

Heavy-Duty Vehicles and Engines for particulate matter (PM)emissions.

By September 24, 2015 - 95% of all trucks used to transportfresh water or well flowback water must meet U.S. EPAs

Final Emission Standards for 2007 and Later Model Year

Highway Heavy-Duty Vehicles and Engines for particulatematter (PM) emissions.

U.S. EPA regulates engineemissions from highway heavy-

duty vehicles based on the vehiclesmodel year.160

None.161 None.162 None.163

15.3

15.4

Truck Idling and Fuel Requirements

All on-road vehicles and equipment - limit unnecessary idlingto 5 minutes, or abide by applicable local or state laws if they

are more stringent.

All on-road and non-road vehicles and equipment - use Ultra-Low Sulfur Diesel fuel (15 ppm of sulfur) at all times.

Starting in 2006, highway diesel

fuel required to meet ultra-lowsulfur (15ppm of sulfur)

requirement.164

Starting in 2010, diesel producedfor use in non-road enginesrequired to meet ultra-low sulfur

(15ppm of sulfur) requirement.165

Motor vehicles with gross weight of 10,001

lbs or more5 minute idling limit in anycontinuous 60-minute period.166

No state-wide regulation. 15-minute idling limit for diesel-

powered motor vehicles with a grossvehicle weight of 10,001 lbs or

more.167


16/19


ENDNOTES

{J1838040.1}

15

158 Pa. C.S. 3217.225 Pa. Code 95.10(b).3Ohio Rev. Code 1509.22.4Ohio Rev. Code 1509.226.5W. Va. Code 22-6-7;James A. Martin, WVDEP Chief, Completion Returns from the Marcellus Shale formation (July 30, 2013).

625 Pa. Code 287.53.7Ohio Admin. Code 1501:9-1-02.8WVDEP Guidance, Large Volume Water Fracture Treatments (Jan. 8, 2010).9W. Va. Code 22-6A-7;W. Va Code R. 35-8-5.6.1025 Pa. Code 78.56.11Ohio Rev. Code 1509.22.12W. Va Code R. 35-8-12.4.1325 Pa. Code 78.56.14Ohio Rev. Code 1509.22.15W. Va Code R. 35-8-12.4.1632 P.S. 693.1;25 Pa. Code 105;see alsoPennsylvania Design and Construction Standards for Centralized Impoundments.17Safety of Centralized Large Pits and Impoundments Used in the Drilling of Horizontal Natural Gas Wells (March 7, 2013).18West Virginia Design and Construction Standards for Centralized Pits;W. Va. Code R. 35-8-16, 17.19W. Va. Code R. 35-8-6.2.j.2058 Pa. C.S. 3218.21Ohio Rev. C 1509.06(A)(8)(c).22W. Va. Code 22-6A-18;W. Va. Code R. 35-8-15.2358 Pa. C.S. 3253;see also25 Pa. Code 78.89,25 Pa. Code 91.33.24Ohio Rev. C 1509.04.25W. Va. Code 22-6A-19.2658 Pa. C.S. 3217;25 Pa. Code 78.71;25 Pa. Code 78.81;25 Pa. Code 78.83;25 Pa. Code 78.83a;25 Pa. Code 78.83b;25 Pa. Code 78.83c;25 Pa. Code 78.84;25 Pa. Code 78.85.27Ohio Rev. Code 1509.17;Ohio Admin. Code 1501:9-1-08.28W. Va. Code 22-6A-24;W. Va. Code R. 35-8-5.7, 9.2.29Federal regulation requires that operators who inject diesel fuels during hydraulic fracturing obtain an Underground Injection Control (UIC) permit prior to injection. This requirement must be met in Pennsylvania, Ohio and West Virginia.30Ohio Admin. Code 1501:9-1-08(C).3158 Pa. C.S. 3222.3258 Pa. C.S. 3222.1.33Ohio Rev. Code 1509.10(A)(9).34W. Va. Code 22-6A-7; W. Va. Code 22-6A-7(e)(5);W. Va. Code R. 35-8-10.3525 Pa. Code 287.53.3625 Pa. Code 78.88.37Ohio Admin. Code 1501:9-1-08(N); Ohio Admin. Code 1501:9-1-08(D)(3).38W. Va. Code R. 35-8-9.2;West Virginia DEP, Office of Oil and Gas, Casing and Cementing Standards and Best Management Practices (December 10, 2012). 3958 Pa. C.S. 3218.2;25 Pa. Code 78.53;25 Pa. Code 78.55;25 Pa. Code 91.34.40Ohio Admin. Code 1501:9-1-07.

41W. Va. Code R. 35-8-5.4, 5.5.42West Virginia General Water Pollution Control Permit, Stormwater Runoff from Oil and Gas Field Construction (June 13, 2013);W. Va. Code 22-6A-7(g)(5);W. Va. Code R. 35-8-9, 18. 4335 Pa. C.S. 7321;25 Pa. Code 78.55.44Ohio Admin. Code 1501:9-9-05.45W. Va. Code 22-6A-7;W. Va. Code R. 35-8-5.7.
http://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.pacode.com/secure/data/025/chapter95/s95.10.htmlhttp://www.pacode.com/secure/data/025/chapter95/s95.10.htmlhttp://codes.ohio.gov/orc/1509.22http://codes.ohio.gov/orc/1509.22http://codes.ohio.gov/orc/1509.226http://codes.ohio.gov/orc/1509.226http://www.legis.state.wv.us/WVCODE/Code.cfm?chap=22&art=1http://www.legis.state.wv.us/WVCODE/Code.cfm?chap=22&art=1http://www.legis.state.wv.us/WVCODE/Code.cfm?chap=22&art=1http://www.dep.wv.gov/oil-and-gas/Resources/Documents/Completion%20Returns%20from%20Marcellus%20Shale%20formation.pdfhttp://www.dep.wv.gov/oil-and-gas/Resources/Documents/Completion%20Returns%20from%20Marcellus%20Shale%20formation.pdfhttp://www.dep.wv.gov/oil-and-gas/Resources/Documents/Completion%20Returns%20from%20Marcellus%20Shale%20formation.pdfhttp://www.pacode.com/secure/data/025/chapter287/s287.53.htmlhttp://www.pacode.com/secure/data/025/chapter287/s287.53.htmlhttp://codes.ohio.gov/oac/1501%3A9-1-02http://codes.ohio.gov/oac/1501%3A9-1-02http://www.dep.wv.gov/oil-and-gas/GI/Documents/Marcellus%20Guidance%201-8-10%20Final.pdfhttp://www.dep.wv.gov/oil-and-gas/GI/Documents/Marcellus%20Guidance%201-8-10%20Final.pdfhttp://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.pacode.com/secure/data/025/chapter78/s78.56.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.56.htmlhttp://codes.ohio.gov/orc/1509.22http://codes.ohio.gov/orc/1509.22http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.pacode.com/secure/data/025/chapter78/s78.56.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.56.htmlhttp://codes.ohio.gov/orc/1509.22http://codes.ohio.gov/orc/1509.22http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.pacode.com/secure/data/025/chapter105/chap105toc.htmlhttp://www.pacode.com/secure/data/025/chapter105/chap105toc.htmlhttp://www.pacode.com/secure/data/025/chapter105/chap105toc.htmlhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-98065/04%208000-PM-OOGM0084%20Design%20and%20Construction%20Stds.pdfhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-98065/04%208000-PM-OOGM0084%20Design%20and%20Construction%20Stds.pdfhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-98065/04%208000-PM-OOGM0084%20Design%20and%20Construction%20Stds.pdfhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://codes.ohio.gov/orc/1509.06http://codes.ohio.gov/orc/1509.06http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.pacode.com/secure/data/025/chapter78/s78.89.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.89.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.89.htmlhttp://www.pacode.com/secure/data/025/chapter91/s91.33.htmlhttp://www.pacode.com/secure/data/025/chapter91/s91.33.htmlhttp://codes.ohio.gov/orc/1509.04http://codes.ohio.gov/orc/1509.04http://www.legis.state.wv.us/WVCODE/ChapterEntire.cfm?chap=22&art=6A&section=19#06Ahttp://www.legis.state.wv.us/WVCODE/ChapterEntire.cfm?chap=22&art=6A&section=19#06Ahttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.pacode.com/secure/data/025/chapter78/s78.71.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.71.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.71.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.81.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.81.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.81.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83a.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83a.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83a.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83b.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83b.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83b.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83c.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83c.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83c.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.84.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.84.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.84.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.85.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.85.htmlhttp://codes.ohio.gov/orc/1509.17http://codes.ohio.gov/orc/1509.17http://codes.ohio.gov/orc/1509.17http://codes.ohio.gov/oac/1501:9-1-08http://codes.ohio.gov/oac/1501:9-1-08http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://water.epa.gov/type/groundwater/uic/class2/hydraulicfracturing/upload/hfdieselfuelsguidance.pdfhttp://water.epa.gov/type/groundwater/uic/class2/hydraulicfracturing/upload/hfdieselfuelsguidance.pdfhttp://water.epa.gov/type/groundwater/uic/class2/hydraulicfracturing/upload/hfdieselfuelsguidance.pdfhttp://codes.ohio.gov/oac/1501:9-1-08http://codes.ohio.gov/oac/1501:9-1-08http://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://codes.ohio.gov/orc/1509.10http://codes.ohio.gov/orc/1509.10http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.pacode.com/secure/data/025/chapter287/s287.53.htmlhttp://www.pacode.com/secure/data/025/chapter287/s287.53.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.88.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.88.htmlhttp://codes.ohio.gov/oac/1501:9-1-08http://codes.ohio.gov/oac/1501:9-1-08http://codes.ohio.gov/oac/1501:9-1-08http://codes.ohio.gov/oac/1501:9-1-08http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.dep.wv.gov/oil-and-gas/Documents/Casing%20and%20Cementing%20Standard.%2012-10-2012.pdfhttp://www.dep.wv.gov/oil-and-gas/Documents/Casing%20and%20Cementing%20Standard.%2012-10-2012.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.pacode.com/secure/data/025/chapter78/s78.53.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.53.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.53.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.55.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.55.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.55.htmlhttp://www.pacode.com/secure/data/025/chapter91/s91.34.htmlhttp://www.pacode.com/secure/data/025/chapter91/s91.34.htmlhttp://codes.ohio.gov/oac/1501:9-1-07http://codes.ohio.gov/oac/1501:9-1-07http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.dep.wv.gov/WWE/Programs/stormwater/csw/Documents/OG%20CSW%20GP.pdfhttp://www.dep.wv.gov/WWE/Programs/stormwater/csw/Documents/OG%20CSW%20GP.pdfhttp://www.dep.wv.gov/WWE/Programs/stormwater/csw/Documents/OG%20CSW%20GP.pdfhttp://www.legis.state.wv.us/wvcode/ChapterEntire.cfm?chap=22&art=6A&section=7#06Ahttp://www.legis.state.wv.us/wvcode/ChapterEntire.cfm?chap=22&art=6A&section=7#06Ahttp://www.legis.state.wv.us/wvcode/ChapterEntire.cfm?chap=22&art=6A&section=7#06Ahttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.pabulletin.com/secure/data/vol43/43-4/132.htmlhttp://www.pabulletin.com/secure/data/vol43/43-4/132.htmlhttp://www.pabulletin.com/secure/data/vol43/43-4/132.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.55.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.55.htmlhttp://codes.ohio.gov/oac/1501:9-9-05http://codes.ohio.gov/oac/1501:9-9-05http://codes.ohio.gov/oac/1501:9-9-05http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://codes.ohio.gov/oac/1501:9-9-05http://www.pacode.com/secure/data/025/chapter78/s78.55.htmlhttp://www.pabulletin.com/secure/data/vol43/43-4/132.htmlhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.legis.state.wv.us/wvcode/ChapterEntire.cfm?chap=22&art=6A&section=7#06Ahttp://www.dep.wv.gov/WWE/Programs/stormwater/csw/Documents/OG%20CSW%20GP.pdfhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://codes.ohio.gov/oac/1501:9-1-07http://www.pacode.com/secure/data/025/chapter91/s91.34.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.55.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.53.htmlhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.dep.wv.gov/oil-and-gas/Documents/Casing%20and%20Cementing%20Standard.%2012-10-2012.pdfhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://codes.ohio.gov/oac/1501:9-1-08http://codes.ohio.gov/oac/1501:9-1-08http://www.pacode.com/secure/data/025/chapter78/s78.88.htmlhttp://www.pacode.com/secure/data/025/chapter287/s287.53.htmlhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://codes.ohio.gov/orc/1509.10http://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://codes.ohio.gov/oac/1501:9-1-08http://water.epa.gov/type/groundwater/uic/class2/hydraulicfracturing/upload/hfdieselfuelsguidance.pdfhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://codes.ohio.gov/oac/1501:9-1-08http://codes.ohio.gov/orc/1509.17http://www.pacode.com/secure/data/025/chapter78/s78.85.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.84.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83c.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83b.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83a.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.83.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.81.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.71.htmlhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://www.legis.state.wv.us/WVCODE/ChapterEntire.cfm?chap=22&art=6A&section=19#06Ahttp://codes.ohio.gov/orc/1509.04http://www.pacode.com/secure/data/025/chapter91/s91.33.htmlhttp://www.pacode.com/secure/data/025/chapter78/s78.89.htmlhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://codes.ohio.gov/orc/1509.06http://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdfhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://www.dep.wv.gov/oil-and-gas/Horizontal-Permits/legislativestudies/Documents/FINAL%20OOG%20Pits%20and%20Impoundments%20Report.pdfhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-98065/04%208000-PM-OOGM0084%20Design%20and%20Construction%20Stds.pdfhttp://www.pacode.com/secure/data/025/chapter105/chap105toc.htmlhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://codes.ohio.gov/orc/1509.22http://www.pacode.com/secure/data/025/chapter78/s78.56.htmlhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://codes.ohio.gov/orc/1509.22http://www.pacode.com/secure/data/025/chapter78/s78.56.htmlhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.legis.state.wv.us/Bill_Status/bills_text.cfm?billdoc=hb401%20enr.htm&yr=2011&sesstype=4X&i=401http://www.dep.wv.gov/oil-and-gas/GI/Documents/Marcellus%20Guidance%201-8-10%20Final.pdfhttp://codes.ohio.gov/oac/1501%3A9-1-02http://www.pacode.com/secure/data/025/chapter287/s287.53.htmlhttp://www.dep.wv.gov/oil-and-gas/Resources/Documents/Completion%20Returns%20from%20Marcellus%20Shale%20formation.pdfhttp://www.legis.state.wv.us/WVCODE/Code.cfm?chap=22&art=1http://codes.ohio.gov/orc/1509.226http://codes.ohio.gov/orc/1509.22http://www.pacode.com/secure/data/025/chapter95/s95.10.htmlhttp://www.ctbpls.com/www/PA/11R/PDF/PA11RHB01950CC1.pdf


17/19


ENDNOTES

{J1838040.1}

16

4625 Pa. Code 91.33.47Ohio Admin. Code 3750-25-25.48W. Va. Code R. 35-8-18.9.49Compliance with Federal air regulations is required in all states regardless of whether or not a permit is required to be obtained. Additionally, the Federal New Source Performance Standards, 40 CFR Part 60, are self-implementing in Pennsylvania and West Virginia. See25 Pa. Code 122Va. Code R. 45-16-4.50Pursuant to thePennsylvania Air Pollution Control Act (APCA), 35 P.S. 4001 et seq. and 25Pa. Code 127.14 (relating to exemptions), the Pennsylvania Department of Environmental Protection (PADEP) may determine sources or classes of sources to be exempt from the plan approval

permitting requirements of 25Pa. Code Chapter 127 (relating to construction, modification, reactivation and operation of sources). If a source does not meet the qualifying criteria for one of PADEPs Air Quality Permit Exemptions, it is subject to plan approval and permitting requirements (u

a request for determination on a case-by-case basis for an exemption is sought and granted by PADEP). SeePennsylvanias Air Quality Permit Exemptions.51Unless subject to an exemption or a permit-by-rule, a facility that contains an air contaminant source is required to obtain either an individual permit-to-install/permit-to-operate or may be eligible for a general permit-to-install/permit-to-operate if one exists. SeeOhio Rev. Code 3704.0

(G);Ohio Rev. Code 3704.011;Ohio Admin. Code 3745-15-05;Ohio Admin. Code 3745-31-01;Ohio Admin Code 3745-31-02;Ohio Admin. Code 3745-31-03.52In West Virginia, a facility tha t meets the definition of a stationary source must obtain either an individual air permit or may be eligible for a generalpermit if one exists. SeeW. Va. Code R. 45-13-2.24; W. Va. Code R. 45-13-5.5340 C.F.R. 60.5375(a).5440 C.F.R. 60.5375(a).5540 C.F.R. 60.5375(a)(2).5640 C.F.R. 60.5375(a)(3).5740 C.F.R. 60.5375(a)(4).58Pennsylvanias Air Quality Permit Exemptions, Category No. 38, at pp. 8-11.59PADEP Frequently Asked Questions, General Permit 5 (GP-5) and Exemption Category No. 38, December 27, 2013, Question/Answer No. 24, at p. 6. 60Ohio Admin. Code 1501:9-9-05(B).61Ohios Draft Natural Gas Completion DraftPermit-by-Rule.62WVDEP General Permit G70-A, Section 5.1. 63WVDEP Response to Public Comment #33 on General Permit G70-A.6440 C.F.R 60.5375(a)(3).65Pennsylvanias Air Quality Permit Exemptions, Category No. 38, at pp. 8 -11.6625 Pa. Code 123.41.67Ohio Admin. Code 1501:9-9-05(B).68

Ohios Proposed Natural Gas Completion Permit-by-Rule.69W. Va. Code R. 45-6-6.1a.70W. Va. Code R. 45-6-4.1, 4.3.71WVDEP General Permit G70-A, Section 5.1.572WVDEP Response to Public Comment #33 on General Permit G70-A.7340 C.F.R. Part 89;40 C.F.R. Part 1039.7440 C.F.R. Part 80.75Pennsylvanias Air Quality Permit Exemptions, Category No. 38, at pp. 8 -11.Additionally, states are generally precluded from establishing emissions limitations for portable non-road engines. SeeClean Air Act Section 209, 42 U.S.C. 7543.76Ohio Admin. Code 3745-31-03-(A)(1)(pp). Additionally, states are generally precluded from establishing emissions limitations for portable non-road engines. SeeClean Air Act Section 209, 42 U.S.C. 7543.77W. Va. Code R. 45-13-1. Additionally, states are generally precluded from establishing emissions limitations for portable non-road engines. SeeClean Air Act Section 209, 42 U.S.C. 7543.7840 C.F.R. Part 89;40 C.F.R. Part 1039.7940 C.F.R. Part 80.80Pennsylvanias Air Quality Permit Exemptions, Category No. 38, at pp. 8 -11. Additionally, states are generally precluded from establishing emissions limitations for portable non-road engines. SeeClean Air Act Section 209, 42 U.S.C. 7543.81Ohio Admin. Code 3745-31-03-(A)(1)(pp). Additionally, states are generally precluded from establishing emissions limitations for portable non-road engines. SeeClean Air Act Section 209, 42 U.S.C. 7543.82W. Va. Code R. 45-13-1. Additionally, states are generally precluded from establishing emissions limitations for portable non-road engines. SeeClean Air Act Section 209, 42 U.S.C. 7543.8340 C.F.R. Part 86.8440 C.F.R. Part 80.85States (except California) are precluded from establishing any emissions limitations other than those required in 40 C.F.R. Part 86. SeeClean Air Act Section 209, 42 U.S.C. 7543.86States (except California) are precluded from establishing any emissions limitations other than those required in 40 C.F.R. Part 86. SeeClean Air Act Section 209, 42 U.S.C. 7543.87States (except California) are precluded from establishing any emissions limitations other than those required in 40 C.F.R. Part 86. SeeClean Air Act Section 209, 42 U.S.C. 7543 . Additionally, motor vehicles are exempted from permitting requirements. SeeW. Va. Code R. 45-13-18840 C.F.R. 60.4230.8940 C.F.R. Part 60, Subpart JJJJ, Table 1. 9040 C.F.R. Part 63, Subpart ZZZZ.
http://www.pacode.com/secure/data/025/chapter91/s91.33.htmlhttp://www.pacode.com/secure/data/025/chapter91/s91.33.htmlhttp://codes.ohio.gov/oac/3750-25-25http://codes.ohio.gov/oac/3750-25-25http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24742&Format=PDFhttp://www.pacode.com/secure/data/025/chapter122/chap122toc.htmlhttp://www.pacode.com/secure/data/025/chapter122/chap122toc.htmlhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24738&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=24738&Format=PDFhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-96215/275-2101-003.pdfhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-96215/275-2101-003.pdfhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-96215/275-2101-003.pdfhttp://codes.ohio.gov/orc/3704.03http://codes.ohio.gov/orc/3704.03http://codes.ohio.gov/orc/3704.03http://codes.ohio.gov/orc/3704.03http://codes.ohio.gov/orc/3704.011http://codes.ohio.gov/orc/3704.011http://codes.ohio.gov/orc/3704.011http://codes.ohio.gov/oac/3745-15-05http://codes.ohio.gov/oac/3745-15-05http://codes.ohio.gov/oac/3745-15-05http://codes.ohio.gov/oac/3745-31-01http://codes.ohio.gov/oac/3745-31-01http://codes.ohio.gov/oac/3745-31-01http://codes.ohio.gov/oac/3745-31-02http://codes.ohio.gov/oac/3745-31-02http://codes.ohio.gov/oac/3745-31-02http://codes.ohio.gov/oac/3745-31-03http://codes.ohio.gov/oac/3745-31-03http://codes.ohio.gov/oac/3745-31-03http://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=1627&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=1627&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=1627&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=1627&Format=PDFhttp://apps.sos.wv.gov/adlaw/csr/readfile.aspx?DocId=1627&Format=PDFhttp://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.ecfr.gov/cgi-bin/text-idx?SID=28eb15e452d814b2637d6908dadbcedd&node=40:7.0.1.1.1.102.297.4&rgn=div8http://www.elibrary.dep.state.pa.us/dsweb/Get/Document-96215/275-2101-003.pdfhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-96215/275-2101-003.pdfhttp://www.elibrary.dep.state.pa.us/dsweb/Get/Document-96215/275-2101-003.pdfhttp://www.dep.state.pa.us/dep/deputate/airwaste/aq/permits/gp/FAQ_GP-5_and_Exemption_38_Final_122713.pdfhttp://www.dep.state.pa.us/dep/deputate/airwaste/aq/permits/gp/FAQ_GP-5_and_Exemption_

Cssd Comparison Table 5.5.14

Documents

Transcript of Cssd Comparison Table 5.5.14