a. The use of electric equipment and electric line power to operate all permanent equipment to mitigate noise and to reduce emissions. Fuel-powered generators used solely for emergency purposes are excluded.

b. Natural gas engines and turbines will be operated and maintained in accordance with the CDPHE and the U.S. EPA regulations and emissions standards.

c. Any combustion device, auto-ignition system, recorder, vapor recovery device, or other equipment used to meet the hydrocarbon destruction or control efficiency requirement shall be installed, calibrated, operated, and maintained in accordance with the manufacturer's recommendations, instructions, and operating manuals.

d. Year-round compliance with the odor standards pursuant to COGCC and CDPHE regulations.

e. Venting is prohibited unless necessary for safety or de minimis volumes for maintenance operations. If emergency venting is required, or if accidental venting occurs, the operator shall provide notice to the city of such event as soon as, but in no event later than, 24 hours from the time of the event, with the information listed above and with an explanation as to the cause and how the event will be avoided in the future.

f. Reduction of emissions from maintenance activities. For planned maintenance activities involving the intentional flaring of gas, the operator shall provide 48-hour advance written notice to the city of such proposed flaring. Such notice shall identify the duration and nature of the flaring event, a description as to why flaring is necessary, what steps will be taken to limit the duration of flaring, and what steps the operator proposes to undertake to minimize similar events in the future.

g. Telemetric control and monitoring systems to detect when pilot lights on control devices are extinguished.

h. Exhaust from all engines, turbines, motors, coolers, and all other equipment must be vented up and away from the nearest residences.

i. Operator shall participate in Natural Gas STAR program or other voluntary programs to encourage innovation in pollution control at sites.

a. Pre-construction baseline air quality testing. Operator shall conduct air sampling for a period of five consecutive days prior to any construction activities for any new central gathering facility or compressor station. Operator shall conduct baseline sampling using a continuous monitoring system that detects wind speed, wind direction, temperature, humidity, pressure, particulate matter (PM2.5 and PM10), sulfur dioxide (SO2), nitrogen oxides (NOx), carbon dioxide (CO), methane, ethane, propane, butane, total volatile organic carbon (VOC), and a sample to be analyzed by EPA Method TO-15 (Determination of Volatile Organic Compounds (VOCs) in Air), which includes benzene, toluene, ethylbenzene and xylene. Operator shall conduct baseline sampling at least 30 days in advance of any construction activities at the central gathering facility or compressor station. Results of the baseline air sampling must be received by the oil and gas manager prior to the issuance of the final OGMP. Results will be used to compare with future samples to determine any change in air quality over time. Both baseline and future samples will also be compared to general air quality measurements in the Aurora area to determine how the air at the oil and gas location compares to the Aurora region.

b. Continuous air monitoring may be required during other phases of operations.

a. Leak detection and repair. The operator shall develop and maintain a leak detection and repair (LDAR) program as required by CDPHE using modern leak detection technologies such as infra-red (IR) cameras. The operator shall conduct quarterly IR camera monitoring or alternative instrument monitoring method of all permanent production equipment.

b. Except when an emergency circumstance would necessitate an immediate repair, operator must repair leaks, as defined by applicable and federal regulations, as quickly as practicable. If more than five days of repair time is needed after a leak is discovered, an explanation of why more time is required must be submitted to the city. In the case when delaying the repair until a scheduled maintenance operation would result in lower total emissions from the leak and repair, operator must communicate with the oil and gas manager to provide calculations of total emissions. At least once per year, the operator shall notify the city five business days prior to an LDAR inspection of its facilities to provide the city the opportunity to observe the inspection for air emissions.

c. Data related to LDAR during any phase shall be reported to the city within 30 days of acquisition.

a. The operator shall respond to ozone air quality action day advisories posted by the CDPHE for the Front Range Area by implementing their suggested air emission reduction measures as feasible. Emission reduction measures shall be implemented for the duration of an ozone air quality action day advisory and may include measures such as:

b. Within 60 days following the conclusion of each annual ozone air quality action day season, operator must submit a report to the city that details which measures it implemented during any ozone air quality action day advisories.

a. Compliance with these air quality requirements and documenting any periods of material noncompliance, including the date and duration of each such deviation and a compliance plan and schedule to achieve compliance;

b. That the equipment at the oil and gas midstream facilities continues to operate within its design parameters, and if not, what steps will be taken to modify the equipment to enable the equipment to operate within its design parameters. The report must contain a certification as to the truth, accuracy, and completeness of the reports, signed by a responsible official. The operator will also provide the city with a copy of any self-reporting submissions that operator provides to the CDPHE due to any incidence of noncompliance with any CDPHE rules or regulations at the oil and gas midstream facilities.

a. A combustion device shall be available at the CGF and compressor station during operations for maintenance or emergencies only.

b. The combustion device must be fired with natural gas and designed to operate with a 98 percent or higher hydrocarbon destruction efficiency.

c. The combustion device must be designed and operated in a manner that will ensure no visible emissions during normal operation. Visible emissions mean observations of smoke for any period or periods of duration greater than or equal to one minute in any 15-minute period during normal operation, pursuant to EPA Method 22. Visible emissions do not include radiant energy or water vapor.

d. The combustion device must be operated with a flame present at all times when emissions may be vented to it, or another mechanism that does not allow uncontrolled emissions.

e. All combustion devices must be equipped with an auto-igniter unless manned while in use.

a. Nature and proximity of adjacent development (design, location, use).

b. Prevailing weather patterns, including wind directions.

c. Type and intensity of the noise emitted.

d. Vegetative cover on or adjacent to the site or topography.

a. A noise management plan specifying the hours of maximum noise and the type, frequency, and level of noise emitted, and the mitigation methods to be employed to control both A and C scale noise.

b. A baseline noise mitigation study shall be conducted to ascertain baseline noise levels at the CGF and compressor station to demonstrate that noise will comply with the city's noise ordinance, and a copy will be provided to the city.