Methane Emission Reduction Technologies for Natural Gas Engines: A Review

Abstract

This review summarizes technologies to reduce methane emissions from natural gas engines with a focus on exhaust treatment. As regulations on methane emissions from natural gas facilities become more restrictive, methane emission reduction technologies become increasingly important. Methane is the second most prevalent human-generated greenhouse gas. In 2020, 197,000 metric tons of methane were released as a result of methane slip. In-cylinder methods such as optimized valve timing and crevice volume reduction are effective in reducing methane slip. Exhaust treatment methods such as catalytic oxidizers and regenerative thermal oxidizers can achieve near 100% methane reduction under certain conditions. Implementation of hydrogen blending and exhaust gas recirculation systems results in a decrease in methane emissions of between 20 and 30%. Future research should focus on testing full-scale catalytic oxidation systems on lean-burn natural gas engines. Research should also focus on implementing regenerative thermal oxidizers on natural gas engines, as well as combining hydrogen blending with these techniques.

1. Introduction

Methane (CH₄) is the second most abundant human-generated greenhouse gas behind carbon dioxide (CO₂). In 2021, 12% of human-generated greenhouse gas (GHG) emissions were methane [1]. There were 25,980,000 metric tons of methane emitted in 2021 [2]. Although methane has a significantly shorter lifespan in the atmosphere than CO₂, methane is 25 times more effective at trapping heat in the atmosphere [3,4]. The concentration of methane in the atmosphere has doubled within the last 200 years and, currently, 20% of all global emissions (human-created and natural) is methane [3]. As the world focuses on the reduction in greenhouse gas emissions, the implementation of hydrogen fuel has become a prevalent research topic. The burning of hydrogen produces no carbon emissions, making it a relatively clean fuel to burn [5,6,7,8,9,10].

Figure 1 shows EPA-reported data for sources of methane emissions in the United States. Natural gas is primarily composed of methane, between 70 and 90% [11]. Methane emissions from natural gas and petroleum sources are the leading source of methane emissions [1]. One of the main uses for natural gas is power generation. Approximately 38% of the United States’ natural gas consumption in 2022 was for electrical power generation [12]. According to the Energy Information Administration (EIA), in 2022, there were roughly 1500 operable natural gas internal combustion engines in the United States being used for power generation [13]. The United States’ natural gas consumption for transportation was 5% in 2022. This includes natural gas engines that are used to drive compressors on gas pipelines, as well as natural gas engines that are used in vehicles [12]. The EIA reports that there are more than 1400 interstate natural gas compression stations that use natural gas engines in the United States [14]. Compressor stations on smaller, intrastate pipelines that move natural gas from wells to the interstate pipelines are larger in number and use primarily natural gas internal combustion engines for compression.

Methane slip is a term that refers to methane that does not combust in a combustion engine. Methane emissions due to methane slip in natural gas systems were 197,000 metric tons in 2020 [2]. Methane slip resulted in 3.0% of all methane emissions from natural gas systems in 2020 [2]. Lean-burn natural gas engines result in higher methane emissions than stoichiometric natural gas engines. Stoichiometric engines, also known as “rich-burn” natural gas engines, are engines that operate at approximately stoichiometric, though slightly rich, air–fuel ratios. Stoichiometric engines result in more complete combustion and less unconsumed methane being released via the exhaust than lean-burn natural gas engines [15]. In a study, a 4-stroke stoichiometric engine produced 0.23 lb. of CH₄ per MMBtu while a 4-stroke lean-burn engine produced 1.25 lb. of CH₄ per MMBtu [16]. Stoichiometric engines typically use three-way catalysts that are effective at reducing methane emissions and are partly responsible for lower methane emissions from this engine class. However, three-way catalysts are designed for stoichiometric engines and are not effective for lean-burn natural gas engines [15]. Lean-burn natural gas engines are more efficient and are commonly chosen over stoichiometric engines where minimizing fuel consumption is favored. By finding effective methane emission reduction methods for lean-burn natural gas engines, the amount of methane released into the atmosphere can be reduced.

The greenhouse gas reporting program (GHGRP), which was codified by Title 40 (Protection of Environment) of the code of federal regulations, is used to monitor sources of greenhouse gas emissions around the country. Facilities are required to report their greenhouse gas emissions under the GHGRP [17]. Subpart W of the GHGRP requires petroleum and natural gas facilities that emit the equivalent of 25,000 metric tons of CO₂ of greenhouse gases a year to report their emissions data to the Environmental Protection Agency (EPA) [18]. Under the Inflation Reduction Act, starting in 2024, facilities that are required to report to the EPA under subpart W will be required to pay $900 per metric ton of CH₄ emitted. This monetary value will increase to $1200 in 2025 and to $1500 in 2026 and beyond [19]. For reference, if a facility emits 900 metric tons of CH₄, the equivalent of 25,000 metric tons of CO₂, in 2026, it will be charged $1.5 million dollars. The EPA-proposed “Good Neighbor Plan” will require upwind states to decrease their greenhouse gas emissions, including methane, to benefit downwind states [20]. Under subpart JJJJ in the new source performance standard (NSPS), the emissions of stationary natural gas engines are regulated by their emission of volatile organic compounds (VOC). Non-emergency natural gas more powerful than 100 HP is restricted to either 0.7 g/HP-h or 80 ppmvd (parts per million by volume, dry) at 15% O₂ [21]. VOCs are defined as non-methane and non-ethane hydrocarbons, so they do not include methane [22]. Aldehydes are also excluded from the VOCs. Methane emissions are targeted in impending regulations through the Inflation Reduction Act and Good Neighbor Plan [19,20]. Once these are implemented, the need for technologies to decrease methane emissions becomes more important.

2. Sources of Methane Slip in Natural Gas Engines

Methane slip refers to methane that does not combust in the operation of a natural gas engine. Between 1% and 5% of the total methane can “slip” through the system [23]. There are several sources of methane slip in the operation of a natural gas engine, including blow-by, valve overlap, and incomplete combustion.

In a numerical analysis of a lean-burn 4-stroke dual-fuel engine, valve overlap resulted in around 30% of the total methane slip at full load [24]. Incomplete combustion from crevices and quenching contributed to the other 70%. Blowby was not considered in this analysis. In this study, valve overlap and incomplete combustion from crevices each resulted in the emission of around 10 g of CH₄ per kWh at any load. Methane slip due to quenching caused 10 g of CH₄ per kWh at full load, and 55 g of CH₄ per kWh at 25% load.

Blow-by, shown in Figure 2, is when methane leaks between the piston ring and the cylinder wall into the crankcase. Unlike the other sources of methane slip, blow-by does not result in unburned methane in the exhaust and therefore is not able to be treated by any exhaust treatment. Blow-by can result in up to 25% of the methane emissions from a natural gas engine [25].

Valve overlap, as seen in Figure 3, occurs when both the inlet and outlet valves are open, and methane bypasses the combustion process and passes into the exhaust. Valve overlap occurs at the end of the exhaust stroke and the beginning of the intake stroke. During the exhaust stroke (upstroke), the exhaust is forced out of the cylinder through the exhaust valve. The inlet valve opens as the piston approaches the top dead center. There is a period when both the inlet and exhaust valves are open at the same time. During this time, the high pressure of the incoming gas flows to the low pressure of the exhaust, causing methane to go directly from the inlet manifold to the exhaust manifold, resulting in unburned fuel in the exhaust [23].

Incomplete combustion can be a result of trapped methane in crevices, quenching near walls, and quenching in lean mixture zones. Crevices (high surface/volume ratio regions) can restrict flame propagation into these volumes allowing methane to go unburned [15]. The amount of unburned hydrocarbons increases exponentially with crevice volume [26]. Quenching effects can also result in incomplete combustion. A quenching effect can occur near the walls of the cylinder. Heat is lost from the gas to the cylinder wall, decreasing the temperature of the gas, and not allowing combustion to occur. Quenching can also occur when there are areas of high λ. Lambda (λ) is the ratio of the actual air–fuel ratio to the stoichiometric air–fuel ratio. In areas of high λ, there is not enough fuel for combustion to occur.

3. In Cylinder Methane Emission Reduction Technologies

One way to decrease blow-by is to decrease the clearance between the piston ring and the cylinder wall, improving the seal and decreasing the amount of gas that can slip into the crankcase, and decreasing the crevice volume where fuel can be protected from the flame. The tradeoff is the improved seal increases the frictional resistance of the piston, decreasing the efficiency of the engine. The methane that leaks into the crankcase creates pressure in the crankcase that needs to be vented. The vented methane from the crankcase can be recycled back into the engine but needs to be filtered. Any oil in the methane that was picked up in the crankcase needs to be removed or damage to the engine may occur [23]. The crevice volume can also be reduced by decreasing the distance between the top ring and the top of the piston. However, this may result in diminished piston reliability since the top ring would be closer to high temperature combustion gases.

Methane slip from valve overlap can be reduced by optimizing the timing for the valves. Valve overlap is necessary because it maximizes the fuel–air mixture mass in the cylinder, maximizing performance [23]. Due to the benefits, valve overlap is tolerable considering it only results in minimal methane slip.

One way to decrease quenching effects in the combustion chamber is to operate the engine closer to stoichiometric [15]. With more fuel (or less air) in the combustion chamber, there is a reduced chance of higher λ areas or heat loss to the cylinder walls resulting in quenching. When operating with a richer mixture, more nitrogen oxides (NO_x) are created due to the higher combustion temperatures [27]. For a lean-burn natural gas engine, running richer is typically not an option due to NO_x permit limits. Controlled auto-ignition is a method that results in stable combustion and less unburned fuel, which has been demonstrated in a 4-stroke industrial natural gas engine [28]. Having improved air–fuel mixing to create a homogenous mixture can reduce high λ areas and decrease quenching in a lean-burn natural gas engine [15]. High-pressure fuel injection is one approach for improving mixing on large bore natural gas integral compressor engines [29]. High pressure fuel injection and precombustion chamber ignition can reduce the frequency of partial combustion and misfires leading to fewer methane emissions [30]. Directional pre-combustion chambers can be designed to target zones of unburned methane to promote more complete oxidation. This approach is demonstrated through CFD simulations in a large bore natural gas 2-stroke engine through design changes to the pre-combustion chamber nozzle [31]

4. Exhaust Methane Emission Reduction Technologies

4.1. Catalytic Oxidation

Catalytic oxidation is a process in which the exhaust flows over a catalyst, usually a precious metal like palladium or platinum in the case of a methane oxidizer. The precious metals are typically dispersed in a porous washcoat such as alumina or ceria that is supported by a metal or ceramic substrate. The catalyst lowers the chemical activation energy thereby accelerating the process of methane reacting with oxygen to produce CO₂ and H₂O. Catalytic oxidizers can be susceptible to poisoning and aging. Catalytic poisoning is a deactivation of the catalyst. This can be a result of the poison chemically altering the catalyst causing it to be less effective or it could simply physically block the catalyst from reacting with the methane [32]. Hydrogen Sulfide (H₂S) can be present in natural gas at concentrations as high as 5% [11]. The presence of hydrogen sulfide in the combustion process results in sulfur dioxide (SO₂) being produced and present in the exhaust of natural gas engines [33]. A concentration as low as 20 ppm of SO₂ can be detrimental to a catalyst’s performance [34]. The source of sulfur in a natural gas engine’s exhaust can be from the natural gas itself but it can also be from the lubrication oil of the engine [33].

Figure 4 plots methane conversion vs. temperature for catalyst studies reported in the literature. The yellow symbol represents the palladium catalyst, purple represents the platinum catalyst, red represents the platinum–palladium alloy catalyst, orange represents the rhodium catalyst, and blue represents the nickel-magnesium alloy. Each catalyst has an ellipsoid to group the catalyst’s performance range. The shaded sections represent exhaust temperature ranges for 4-stroke and 2-stroke lean-burn natural gas engines. The exhaust temperature range for 2-stroke lean-burn natural gas engines is 280–380 °C. For 4-stroke lean-burn natural gas engines, it is 395–520 °C [29,35,36]. Light gray represents 2-stroke and dark gray represents 4-stroke.

Platinum and nickel-magnesium catalysts are unable to achieve 100% methane conversion at low enough temperatures for either type of lean-burn natural gas engine. Palladium and rhodium catalysts could achieve 100% conversion at temperatures within the 4-stroke temperature range but not the 2-stroke temperature range. The platinum-palladium catalyst is the only catalyst that could achieve 100% conversion within the temperature range of the 2-stroke natural gas engine. The overwhelming majority of studies focusing on the oxidation of methane, including the ones summarized in Figure 4, are small-scale tests either using bottled gas or just a portion (i.e., slipstream) of the exhaust of a natural gas engine. There were no full-scale methane oxidation catalyst engine studies found in the literature. Furthermore, the methane oxidation catalysts studied are under development and are not commercially available.

4.1.1. Palladium

Palladium is a common precious metal selected as a methane oxidation catalyst and has been studied heavily [34,37,38,39,40,41,42,43,44,45,46,47,48,49,50,51,52,53,54,55,56,57,58,59,60,61,62,63,64,65,66,67,68,69,70,71,72,73,74,75,76,77,78]. Palladium is capable of 100% methane conversion at temperatures as low as 450 °C [40]. Palladium is effective in methane oxidation at the exhaust temperatures for a 4-stroke lean-burn natural gas engine, but its threshold is not low enough to be fully effective for a 2-stroke natural gas engine [29,35,36]. The most difficult challenge with palladium as a methane oxidation catalyst is its susceptibility to aging and poisoning. At a constant temperature of 385 °C, a palladium catalyst dropped from 70% to 10% methane conversion after 1500 h of use [37]. When a palladium catalyst was hydrothermally aged, the T₇₅ (temperature to achieve 75% methane conversion) increased from 359 °C to 492 °C, a 21% increase [39]. When SO₂ is present in the methane stream, the palladium becomes poisoned. With the presence of 20% SO₂, the T₁₀₀ value increased by 12% [34].

4.1.2. Platinum

Platinum is another common choice for a methane oxidation catalyst. There are many studies on platinum catalysts for methane [37,39,40,42,50,53,62,67,69,74,79,80,81,82]. The required temperature for a solely platinum catalyst is much higher than the operating range of both 4-stroke and 2-stroke engines [29,35,36]. The benefit of a platinum catalyst is that it is less susceptible to the effects of aging and poisoning than a catalyst like palladium. As noted above, palladium had an increase in T₇₅ of 359 °C to 492 °C, a 21% increase, after hydrothermal aging. After the same hydrothermal aging process platinum had only a 6% increase in temperature going from 541 °C to 632 °C [39]. At a constant temperature of 385 °C, a platinum catalyst dropped from 35% to 25% methane conversion after 1500 hours of use, significantly better than the performance of palladium [37].

4.1.3. Palladium-Platinum Alloy

To have the high aging and poisoning resistivity of platinum and the lower temperature requirement of palladium, the two metals are often combined into an alloy [37,38,39,48,49,50,51,53,62,67,69,74,81,82,83,84]. The ratios of platinum to palladium range from 1:5 to 5:1 [37,38,39,40]. The Pt-Pd alloy results in a wide range of performances based on this ratio. A T₁₀₀ value as low as 325 °C and as high as 525 °C is achieved. After 1500 hours of use, the methane conversion rate for a Pt-Pd alloy (1:1) dropped from 79% to 60%, while the conversion rate for a Pt-Pd alloy (2:3) dropped from 80% to 55% at 385 °C [37]. For a Pt-Pd alloy (4:1), the T₇₅ value increased by 14% after hydrothermal aging, compared to the palladium and platinum catalysts, which had increases of 21% and 6%, respectively [39]. While not as resistant to aging as the platinum catalyst, Pt-Pd catalysts achieve methane oxidation at lower temperatures. The T₇₅ of the Pt-Pd alloy without aging was 437 °C, significantly lower than the T₇₅ value for the platinum catalyst, which was 582 °C [39].

4.1.4. Rhodium

Rhodium catalysts are effective in 4-stroke lean-burn natural gas engines but require temperatures too high to operate effectively in 2-stroke engines. Rhodium is an under-studied catalyst for methane oxidation [34,74,77]. Palladium catalysts are relatively resistant to sulfur poisoning while in dry conditions; however, they are much more susceptible to sulfur poisoning while in wet conditions [34]. A variety of rhodium-based catalysts were tested and compared to a palladium catalyst with the presence of water and sulfur. The catalysts used were a 2% by-weight palladium catalyst using a ZSM-5 (SiO₂/Al₂O₃) washcoat and a 2% by-weight Rhodium Catalyst also using a ZSM-5 washcoat. Under standard conditions with no H₂O or SO₂ present, the rhodium catalyst achieved 100% methane conversion at a temperature of 425 °C and the palladium achieved it at a temperature of 462 °C. When H₂O and SO₂ were introduced into the fuel stream, the T₁₀₀ values for rhodium increased to 550 °C. The palladium catalyst was not able to achieve 100% conversion and only achieved 95% at the peak temperature of 600 °C. For reference, the rhodium achieved 95% at 500 °C [34]. The main drawback of using rhodium is that it is much more expensive than palladium and platinum. In the last 10 years, the cost of palladium has been about $60/g and platinum has been approximately $35/g. In that same time frame, rhodium has reached as high as $900/g and is usually well over $100/g [85].

4.1.5. Nickel-Magnesium Alloy

A catalyst consisting of a nickel magnesium alloy has been used as an alternative to palladium, which is susceptible to being degraded with a high concentration of water [41,86,87,88,89,90,91,92]. After 40 hours of use, a pallidum catalyst’s T₁₀₀ value increased from 450 °C to 575 °C when used with a methane stream including 10% H₂O. By comparison, in the same conditions, the T₁₀₀ value for a Ni-Mg (9:1) catalyst remains constant at 550 °C after 40 hours [41]. However, 550 °C is higher than the exhaust temperature range for both 4-stroke and 2-stroke lean-burn natural gas engines. More work would have to be done to determine if a nickel-magnesium catalyst can be effective for natural gas lean-burn engines.

4.1.6. Three-Way Catalyst

A three-way catalyst is used to reduce nitrogen oxides (NO_x) and oxidize; carbon monoxide (CO); and hydrocarbons (HC), including methane [93,94]. Three-way catalysts are effective at reducing the emissions of all three and can ideally achieve a near 100% emission reduction [94]. A study performed on a stoichiometric 4-stroke natural gas engine using a three-way catalyst reported catalytic destruction of methane from 1.4 g/bhp-h to 0.6 g/bhp-h, a 57% reduction. For the same datapoint the result showed a 100% reduction in NO_x, from 11.4 g/bhp-h to 0 g/bhp-h, and a 98% reduction in CO emissions, from 8.75 g/bhp-h to 0.2 g/bhp-h [95]. Three-way catalysts are made of many of the same metals that can be used for lean-burn natural gas engine oxidation catalysts such as platinum, palladium, and rhodium. However, three-way catalysts are specifically tuned to reduce the emissions of NO_x, CO, and HC at stoichiometric conditions (λ ≈ 1) [15,93]. A three-way catalyst uses NO_x as an oxidizer. As the λ value increases and the concentration of NO_x in the exhaust decreases. The three-way catalyst becomes less effective at oxidizing HC and reducing NO_x emissions. As λ increases, CO oxidation efficiency is relatively unaffected. In a study, at λ = 1, NO_x reduction efficiency and HC oxidation efficiency was near 100%. At λ = 1.1, the NO_x reduction efficiency dropped to 10% and the HC oxidation efficiency dropped to 55% [93]. For stoichiometric natural gas engines, a three-way catalyst is quite effective, but to have effective methane reduction for lean-burn natural gas engines, a catalyst other than a three-way catalyst needs to be used.

4.2. Thermal Oxidizers

One method to oxidize methane that does not require a catalyst is a regenerative thermal oxidizer (RTO). Many RTOs consist of two porous heat beds connected by an oxidation chamber [96]. Figure 5 and Figure 6 show schematics of two different RTOs. The heat beds are usually made from ceramic but there are instances where they are made of gravel supported by a steel structure [96,97]. In an RTO, the exhaust gas containing methane flows through the first heat bed, which acts as a preheater. Once the exhaust reaches the target temperature, the methane oxidizes and releases heat. Methane oxidation releases 802.7 kJ/mol, as seen in eqn. 1 [98]. The gas then leaves the oxidation chamber and transfers heat to the second heat bed, which acts as a heat sink. To maintain this process, flow through the RTO is periodically reversed, and the second bed becomes the preheater and the first bed becomes the heat sink. The system eventually reaches steady state and is self-sustaining. The energy released from the oxidation process provides heat to sustain the process. When an RTO is initially started, energy is required to heat the gas to instigate oxidation. Electrical heaters are used in the oxidation chamber to achieve this. These heaters can be in the range of 22–40 kW depending on the size of the RTO [96,97,98,99].

CH₄ + 2O₂ → CO₂ + 2H₂O ΔH₍₂₉₈₎ = −807 kJ/mol(1)

The primary use of RTOs has been to oxidize methane gas from ventilation air methane (VAM) from coal mines [100]. Due to their size and complexity, there have not been many applications for using RTOs on natural gas engines. The benefit of using an RTO to oxidize methane in the exhaust of a lean-burn natural gas engine is that no matter the temperature of the exhaust gas, it can be heated to induce oxidation. The exhaust temperature range for 2-stroke and 4-stroke lean-burn natural gas engines are 280–380 °C and 395–520 °C, respectively [29,35,36]. There may not be a need for heat to be added for a 4-stroke engine operating within the higher range of exhaust temperatures. For the lower end of the exhaust temperature range for 4-stroke and for the entire 2-stroke exhaust temperature range, heat will need to be added to the combustion chamber to induce oxidation. Table 1 summarizes results from RTO performance studies reported in the literature [90,91,92,96].

Regenerative Catalytic Oxidizers (RCO) have a similar layout to an RTO but have a catalyst in the heat bed. This can decrease the operating temperature required for complete oxidation, with many RCOs requiring 320–430 °C while RTOs require ranges closer to 760–820 °C. A study using an RCO on natural gas/diesel dual-fuel engines saw a more than 90% reduction in hydrocarbon emissions [101]. This RCO operated at temperatures between 300 and 700 °C.

Table 1

Methane removal efficiency of different RTOs, data from [90,91,92,96].

Operational Temperature	Heated Wire Power	Methane Concentration	Methane Removal Efficiency	Source
300–513 °C	40 kW	1190 ppm	91.5%	[97]
300–382 °C	40 kW	21 ppm	95.2%	[97]
300–440 °C	40 kW	3020 ppm	99.5%	[97]
300–418 °C	22 kW	634 ppm	98.5%	[97]
300–436 °C	22 kW	595 ppm	98.3%	[97]
600–900 °C	-	0.5–1.1%	90–100%	[98]
1000–1200 °C	-	0.3–0.8%	95%	[99]
400–700 °C	-	3500 ppm	90–100%	[102]

Prabhu Energy labs has developed a device to counteract the common problems with RTOs. Their device, the Oxiperator, consists of a non-porous section where heat freely transfers from the outlet gas to the inlet gas, and a porous section where oxidation of the methane occurs, as seen in Figure 7. This eliminates the need for the flow to be reversed periodically. The Oxiperator has an operating temperature of approximately 900 °C, meaning heat addition would likely be required for 4-stroke and 2-stroke lean-burn natural gas engines to be effective. The device is scalable, and components can be grouped together to meet the needs of different applications [95].

4.3. Exhaust Gas Recirculation

Exhaust gas recirculation (EGR) is a process in which a portion of the exhaust gas is recirculated back into the engine. The methane in the exhaust that is recirculated will be used in the combustion process [15]. Up to 25% of the exhaust is used in an EGR system so 75% of the exhaust goes untreated for methane slip unless another method of methane reduction is used. With EGR rates above 25%, the cylinder pressure and brake efficiency drop off significantly [103]. An EGR cooler is required to cool the exhaust. The EGR cooler can result in water droplets forming, which can increase wear on the turbocharger [15]. An EGR system can result in a 20% reduction in methane emissions [104]. A study performing EGR sweeps on a natural gas engine achieved a 45% reduction in methane emissions using an EGR rate of 14.7% [28]. EGR would need to be paired with another methane emission reduction method such as a catalytic oxidizer or an RTO to achieve a 100% methane reduction. Other benefits of an EGR system are improved combustion stability and a decrease in NO_x emissions [15,104].

5. Hydrogen Blending

Hydrogen is an energy-dense fuel that can be blended with natural gas and used in lean-burn natural gas engines resulting in reduced emissions. When hydrogen is burned, no carbon is produced, and by blending it with natural gas, the amount of carbon released is reduced [5,6,7,8]. With minor adjustments, the current natural gas transportation infrastructure can handle hydrogen blends up to 15% [5]. At a hydrogen blend above 20%, the safety risk becomes significantly higher than pure natural gas [5]. With a blend of 20% hydrogen, total hydrocarbon emissions decreased by up to 25% [6,7,9,10]. Emissions of CO₂ and CO were also decreased by 10% [7]. The adiabatic flame temperature of hydrogen is higher than natural gas, which results in an increase in thermal efficiency [9,10]. This also results in an increase in NO_x emissions. The increase in NO_x would need to be addressed by the 3-way catalyst or more EGR for stoichiometric engines or by operating the engine leaner for lean burn engines. Hydrogen blending is not a solution to remove 100% of CH₄ emissions from a lean-burn natural gas engine. Hydrogen blending could be paired with a catalytic or thermal methane oxidation method to achieve complete CH₄ emission removal.

The main obstacle to hydrogen blending is there is no dedicated infrastructure to produce green hydrogen [5]. Green hydrogen is typically hydrogen produced using electrolysis with electricity from green power sources such as wind power, solar power, etc. Blue hydrogen is hydrogen produced using fossil fuels, which results in the production of hydrogen and CO₂. The production of blue hydrogen includes carbon capture. The current hydrogen production infrastructure generates grey hydrogen. Grey hydrogen is produced the same way as blue hydrogen but does not have carbon capture [5]. By blending grey hydrogen in with natural gas, it is only shifting the carbon emissions earlier in the process. For hydrogen blending to be an effective tool in reducing greenhouse gas emissions, blue or green hydrogen would need to be used.

6. Conclusions

For lean-burn natural gas engines, decreasing valve overlap, trapped methane in crevices, and quenching effects are key ways to decrease the amount of methane slipping into the exhaust. Exhaust treatment methods such as catalytic oxidizers could be effective in reducing the methane of lean-burn natural gas engines.

Palladium-based catalysts and rhodium-based catalysts could achieve nearly 100% methane reduction for 4-stroke engines, operating at temperatures between 395 °C and 530 °C. For the exhaust temperature range of 2-stroke engines, operating between 280 °C and 330 °C, palladium-based catalysts and rhodium-based catalysts would be ineffective. The disadvantage of a palladium catalyst is that it is susceptible to aging and poisoning. Rhodium is resistant to aging and poisoning but is much more expensive than palladium and platinum. The benefit of using a regenerative thermal oxidizer is that there is no risk of aging and poisoning.

Platinum-based catalysts have the advantage of being resistant to aging and being relatively inexpensive. The downside to platinum catalysts is that they are not effective in the temperature ranges of 2-stroke engines. Additionally, nickel-based catalysts would not be an effective catalyst for either 2-stroke or 4-stroke lean-burn natural gas engines.

Platinum-palladium alloys could achieve a nearly 100% reduction in methane emissions at temperatures as low as 325 °C with moderate resistance to aging and poisoning. This is well within the temperature range for 2-stroke and below the temperature range for 4-stroke lean-burn natural gas engines. Pt-Pd catalysts are the best option for catalytic methane reduction. However, they still can be partially affected by poisoning and would not be able to achieve 100% methane reduction at the very bottom portion of the 2-stroke exhaust temperature range.

The benefit of using a regenerative thermal oxidizer is that there is no risk of aging and poisoning. Additionally, RTOs can operate with any exhaust temperature by using heat addition in the oxidation chamber and using the released heat from methane oxidation to preheat the exhaust. RTOs would be most effective in lean-burn natural gas engines. They would not be effective in reducing NO_x emissions that are present at low concentrations in exhaust for lean-burn natural gas engines. The drawback of using many RTOs for natural gas engines is their size, as RTOs are quite large. Smaller thermal oxidizer designs could be effective in natural gas engines.

Methods such as hydrogen blending, at a 20% hydrogen blend, and exhaust gas recirculation can achieve a 20–30% reduction in methane emission for lean-burn natural gas engines. For these methods to achieve a 100% reduction, they must be paired with a catalytic or thermal oxidizer.

7. Future Directions

Catalytic oxidation of methane is a heavily researched topic, but more full-scale testing needs to be conducted, especially on lean-burn natural gas engines. Methane oxidation catalyst formulations that are resistant to degradation and poisoning are needed. Most research regarding thermal oxidizers employed to reduce methane emissions does not focus specifically on using them on lean-burn natural gas engines. Rather, the literature focuses on VAM reduction. Dedicated research using a thermal oxidizer on a lean-burn natural gas engine could prove beneficial. Hydrogen blending and EGR systems are approximately 30% effective at methane emission reduction, and research combining hydrogen blending or an EGR system with a catalytic oxidizer or thermal oxidizer could result in more complete methane emission reductions.

Author Contributions

Conceptualization, A.H. and D.O.; methodology, A.H.; investigation, A.H.; writing—original draft preparation A.H.; writing—review and editing D.O.; visualization A.H. All authors have read and agreed to the published version of the manuscript.

Data Availability Statement

No new data was created or analyzed in this study. Data sharing is not applicable to this article.

Conflicts of Interest

The authors declare no conflict of interest.

Footnotes

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Figures and Table

Figure 1. EPA-reported estimates of sources of methane using data from 1990–2021 [2].

Figure 2. Diagram of blow-by in an internal combustion engine.

Figure 3. Diagram of valve overlap occurring between exhaust and intake stroke.

Figure 4. Percentage of methane conversion for Pd, Pt, Pt:Pd, Rh, and Ni:Mg catalysts with respect to gas temperature, data from [34,37,38,39,40,41], including exhaust temperature ranges for 2-stroke and 4-stroke lean-burn natural gas engines, data from [29,35,36]; data used to generate this figure are summarized in Table A1.

Figure 5. RTO schematic in which valves 1 and 4 open for flow to go left to right and valves 2 and 3 for flow to go right to left Adapted with permission from Ref. [99].

Figure 6. RTO schematic in which flow switches from clockwise (a) to counterclockwise (b). Adapted with permission from Ref. [96].

Figure 7. Schematic of Prabhu Energy Labs’ Oxiperator [95], (Courtesy Prabhu Energy Labs).

Appendix A

Table A1

Summary of data used to generate Figure 4 and summary of test conditions and performance of several types of oxidation catalysts, data from [33,37,38,39,40,41]. Many of the values of Temperature and Methane Conversion were approximated from graphical data. (NR) denotes no data reported and (N/A) denotes that catalyst did not achieve the corresponding percentage of methane conversions within the test conditions.

Catalyst	Ratio	Density (g/m3)	CH4 (ppm)	O2 (%)	H2O (%)	SO2 (ppm)	Aged	T (°C)	Conversion (%)	Source
Pd	-	10,400	2000	10.5	10	-	No	385	70	[37]
Pd	-	10,400	2000	10.5	10	-	1500 h of use	385	10	[37]
Pd	-	51,800	2000	10.5	10	-	No	385	77	[37]
Pd	-	51,800	2000	10.5	10	-	1500 h of use	385	25	[37]
Pt	-	9600	2000	10.5	10	-	No	385	35	[37]
Pt	-	9600	2000	10.5	10	-	1500 h of use	385	25	[37]
Pt:Pd	1:1	20,800	2000	10.5	10	-	No	385	79	[37]
Pt:Pd	1:1	20,800	2000	10.5	10	-	1500 h of use	385	60	[37]
Pt:Pd	2:3	27,900	2000	10.5	10	-	No	385	80	[37]
Pt:Pd	2:3	27,900	2000	10.5	10	-	1500 h of use	385	55	[37]
Pt:Pd	1:5	12,000	7500	NR	4.89	-	No	325	100	[38]
								300	75
								300	50
Pt:Pd	3:41	4400	7500	NR	4.89	-	No	525	100	[38]
								425	75
								400	50
Pt:Pd	3:40	4300	7500	NR	4.89	-	No	350	100	[38]
								325	75
								300	50
Pt:Pd	10:47	5700	7500	NR	4.89	-	No	375	100	[38]
								350	75
								325	50
Pd	-	210	7500	NR	4.89	-	No	N/A	100	[38]
								550	75
								500	50
Pd	-	1400	7500	NR	4.89	-	No	450	100	[38]
								400	75
								350	50
Pd	-	5297	100,000	20	-	-	No	359	75	[39]
								321	50
								282	25
Pd	-	5297	100,000	20	-	-	Hydrothermally	426	75	[39]
								394	50
								355	25
Pd	-	5297	100,000	20	5	-	Hydrothermally	492	75	[39]
								452	50
								421	25
Pt	-	3355	100,000	20	-	-	No	582	75	[39]
								541	50
								477	25
Pt	-	3355	100,000	20	-	-	Hydrothermally	634	75	[39]
								607	50
								556	25
Pt	-	3355	100,000	20	5	-	Hydrothermally	632	75	[39]
								604	50
								557	25
Pt:Pd	4:10	3355	100,000	20	-	-	No	437	75	[39]
								403	50
								360	25
Pt:Pd	4:10	3355	100,000	20	-	-	Hydrothermally	471	75	[39]
								433	50
								380	25
Pt:Pd	4:10	3355	100,000	20	5	-	Hydrothermally	548	75	[39]
								497	50
								455	25
Pd	-	2260	3000	12	6	-	No	450	100	[40]
								400	75
								392	50
Pd	-	2260	3000	12	12	-	No	550	100	[40]
								450	75
								448	50
Pd	-	2260	3000	1.5	12	-	No	N/A	50	[40]
Pt	-	2295	3000	12	6	-	No	N/A	50	[40]
Pt	-	2295	3000	12	12	-	No	N/A	50	[40]
Pt	-	2295	3000	1.5	12	-	No	550	100	[40]
								500	75
								500	50
Pt:Pd	1:5	2437	3000	12	6	-	No	500	100	[40]
								400	75
								393	50
Pt:Pd	1:5	2437	3000	12	12	-	No	500	100	[40]
								435	75
								427	50
Pt:Pd	1:5	2437	3000	1.5	12	-	No	N/A	50	[40]
Rh	-	2 wt%	2500	10	-	-	No	425	100	[33]
								350	75
								325	50
Rh	-	2 wt%	2500	10	5	-	No	500	100	[33]
								400	75
								387	50
Rh	-	2 wt%	2500	10	-	20	No	500	100	[33]
								462	75
								437	50
Rh	-	2 wt%	2500	10	5	20	No	550	100	[33]
								487	75
								475	50
Pd	-	2 wt%	2500	10	-	-	No	462	100	[33]
								362	75
								350	50
Pd	-	2 wt%	2500	10	5	-	No	475	100	[33]
								425	75
								412	50
Pd	-	2 wt%	2500	10	-	20	No	550	100	[33]
								475	75
								425	50
Pd	-	2 wt%	2500	10	5	20	No	N/A	100	[33]
								525	75
								512	50
Ni:Mg	9:1	6,250,000	10,000	10	10	-	No	550	100	[41]
								500	75
								480	50
Ni:Mg	9:1	6,250,000	10,000	10	10	-	40 h of use	550	100	[41]
								540	75
								504	50
Pd	-	1 wt%	10,000	10	10	-	No	450	100	[41]
								425	75
								396	50
Pd	-	1 wt%	10,000	10	10	-	40 h of use	575	100	[41]
								540	75
								507	50

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