Natural Gas Trading: Drivers & Volatility

The Global Natural Gas Market: Structure and Key Benchmarks

Natural gas is the second-largest primary energy source in the world after crude oil, accounting for roughly a quarter of global energy consumption. Unlike oil, which has a largely unified global price (with Brent and WTI as the two dominant benchmarks), natural gas markets are fragmented into regional blocs because transporting the commodity is far more capital-intensive.

The three major pricing regions are North America, Europe, and Asia-Pacific. In North America, the Henry Hub in Louisiana is the delivery point for the benchmark NYMEX natural gas futures contract traded on the CME Group. This price, denominated in US dollars per million British thermal units (MMBtu), is the single most referenced natural gas price in the world. In Europe, the Title Transfer Facility (TTF) in the Netherlands has become the dominant benchmark, particularly after Russian supply disruptions brought TTF into global headlines. In Asia, the Japan Korea Marker (JKM) serves as the spot LNG price reference.

India sits within the Asian LNG import sphere, and its domestic gas prices are set through a government-administered formula under the Administered Pricing Mechanism (APM), which references a weighted average of international benchmarks. However, the prices of LNG procured through the spot market closely follow JKM, while the MCX natural gas futures contracts in India are benchmarked to Henry Hub, with a currency conversion into Indian Rupees.

Understanding these benchmark relationships matters for Indian traders because it means that the price you see on MCX is not a pure reflection of domestic demand and supply. Instead, it is primarily driven by U.S. market dynamics - weather in the American Midwest, U.S. production from shale formations like the Permian Basin and the Marcellus Shale, and U.S. LNG export capacity. These international variables then interact with the USD/INR exchange rate to determine the INR price you trade on MCX.

The global LNG trade has grown enormously over the past two decades and has increasingly linked regional markets. When European prices spiked in 2021 and 2022 due to supply tensions, Asian buyers competed aggressively for LNG cargoes, lifting JKM prices to historic highs. This interconnectedness means that a trader tracking Indian MCX natural gas prices must maintain at least a broad awareness of global supply-demand balances, not just domestic news.

Major natural gas producers globally include the United States (the world's largest producer thanks to the shale revolution), Russia, Iran, Qatar, Australia, and Canada. Among these, the United States and Qatar are also the largest LNG exporters, giving them outsized influence on the global traded market. Any disruption to U.S. export terminals or Qatari facilities can send Asian LNG spot prices sharply higher, indirectly influencing sentiment in Indian commodity markets as well.

India's Domestic Natural Gas Landscape

To understand why natural gas trading is relevant for Indian market participants - not just as a speculative instrument but also as a hedging tool - it helps to understand the structure of India's domestic gas sector.

India produces natural gas primarily from offshore fields in the Krishna-Godavari basin and from various fields operated under Production Sharing Contracts and Revenue Sharing Contracts awarded by the government. However, domestic production has historically fallen short of demand, making India a significant net importer of LNG. The government has set an ambitious target of raising natural gas's share in India's primary energy mix from around 6 percent to 15 percent by 2030, signalling a continued expansion of gas consumption infrastructure.

The consuming sectors in India are diverse. Fertiliser plants are among the largest consumers, as natural gas is a key feedstock for urea production. Power generation, though cyclical and competitive against coal, also consumes significant volumes. City gas distribution (CGD) networks, which supply compressed natural gas (CNG) to vehicles and piped natural gas (PNG) to households and commercial establishments, have been expanding rapidly under a government push. Industrial consumers in sectors like glass, ceramics, textiles, and chemicals rely on natural gas for process heat.

For businesses in these sectors, movements in international gas prices create real cost pressures. A fertiliser manufacturer importing LNG at spot rates faces input cost volatility that can significantly affect its margins. City gas distribution companies must balance the cost of procuring gas against the regulated retail prices they can charge consumers. This is precisely where commodity futures on MCX have a legitimate hedging role, though corporate treasury use of commodity futures in India remains less widespread than in more mature markets.

The Petroleum and Natural Gas Regulatory Board (PNGRB) regulates downstream gas infrastructure in India, including pipelines and city gas networks. Upstream exploration and production is governed by the Ministry of Petroleum and Natural Gas and the Directorate General of Hydrocarbons (DGH). The Reserve Bank of India (RBI) is relevant insofar as LNG imports involve foreign exchange transactions and fall within India's current account.

For retail traders, this domestic context matters for two reasons. First, it provides a fundamental backdrop that can support or undermine trends observed in internationally benchmarked MCX prices. During periods of high domestic demand - for example, peak summer cooling demand or post-monsoon fertiliser procurement seasons - the physical market tightness can support MCX prices. Second, any government policy change related to domestic gas pricing, import duty structures, or subsidy regimes can suddenly shift the domestic price landscape, creating sharp reactions in MCX futures.

MCX Natural Gas Futures: Contract Mechanics

In India, the primary regulated exchange for trading natural gas futures is the Multi Commodity Exchange of India (MCX), which operates under SEBI oversight. Understanding the contract specifications is essential before placing your first trade.

The MCX natural gas futures contract is denominated in Indian Rupees per MMBtu. Each lot represents 1,250 MMBtu of natural gas. The minimum price fluctuation (tick size) is typically 10 paise per MMBtu, and the initial margin requirement is set by MCX based on SEBI's framework for commodity derivatives, varying with market volatility. MCX also offers a mini natural gas contract with a smaller lot size, which allows retail participants with smaller capital bases to take positions without the full exposure of the standard contract.

Contracts are available for multiple monthly expiries, typically up to about twelve months forward, though liquidity is heavily concentrated in the near-month contract. The expiry date is usually around the 25th of the contract month, and final settlement is cash-settled against the CME Henry Hub natural gas futures price after currency conversion at the RBI reference rate. There is no physical delivery of natural gas through MCX.

This cash-settled, Henry Hub-referenced design has important implications. It means the MCX price is essentially the U.S. Henry Hub price translated into Rupees. If Henry Hub rises from $2.50/MMBtu to $3.00/MMBtu - a 20 percent increase - and the USD/INR exchange rate remains stable, the MCX price should move approximately 20 percent. However, if the Rupee simultaneously weakens from ₹83 to ₹85 per dollar, the INR price impact will be even larger. Conversely, Rupee appreciation can cushion or even reverse the INR impact of a Henry Hub rise.

This dual exposure to both the underlying commodity price and the exchange rate is a critical differentiator that Indian traders must account for. A trader who is broadly bearish on natural gas prices but expects Rupee depreciation faces a mixed signal - commodity directional view versus currency directional view - that makes the trade more complex than a simple directional call on the commodity.

MCX also offers natural gas options contracts, which allow participants to take directional views or hedge positions with defined maximum loss (the option premium). Options strategies on natural gas can be particularly useful during high-volatility periods when futures margins expand and the cost of holding directional positions increases significantly.

Trading hours on MCX extend from 9:00 AM to 11:30 PM IST (10:00 PM during Indian daylight saving adjustments, though India itself does not observe daylight saving - the adjustment reflects U.S. daylight saving changes that shift the overlap with U.S. market hours). This extended window allows Indian traders to participate during U.S. market hours, when natural gas volatility is highest following the weekly EIA storage report release.

Key Price Drivers: Weather and Seasonal Demand

No single factor drives natural gas prices more powerfully and unpredictably than weather. This is the fundamental reason natural gas is often called the most weather-sensitive of all major commodity markets.

In the United States - whose market sets the Henry Hub benchmark that underlies MCX contracts - natural gas is used extensively for both heating in winter and power generation for air conditioning in summer. This creates two seasonal demand peaks. The winter heating demand season typically runs from November through March, while the summer cooling demand season peaks from June through August. Between these peaks, the spring and autumn "shoulder seasons" are characterised by lower demand, weaker prices, and active gas injection into underground storage.

The severity of winter heating demand is measured by "Heating Degree Days" (HDD), a statistical construct that quantifies how far average daily temperatures fall below a baseline of 65 degrees Fahrenheit. The colder the winter, the higher the HDD count, and the more natural gas is burned for heating. Similarly, "Cooling Degree Days" (CDD) measure summer heat intensity and its associated air-conditioning demand. Natural gas traders track HDD and CDD forecasts obsessively during the demand seasons because an unexpected cold snap or heat wave can swing weekly EIA storage draws by billions of cubic feet and cause sharp price moves.

Weather forecasting services that specialise in energy demand - providing two-week, six-week, and seasonal outlooks - are closely followed by professional natural gas traders. The National Oceanic and Atmospheric Administration (NOAA) in the U.S. publishes seasonal temperature outlooks that can move natural gas futures even months before the relevant season arrives.

From an Indian perspective, domestic seasonal factors also affect the local narrative around natural gas, even though MCX prices are benchmarked to the U.S. In India, the monsoon season (June to September) reduces the operational output of some industries and shifts energy demand patterns. The post-monsoon period typically sees a pickup in industrial activity and therefore gas consumption. Winter in North India can increase demand for PNG in city gas distribution networks. During extreme summer heat waves in India, the power sector draws more gas for peaking power plants, supporting domestic demand.

The El Niño and La Niña climate phenomena deserve special mention. These large-scale ocean-atmosphere interactions significantly influence winter temperatures across North America. La Niña events, associated with cooler temperatures in the northern United States, tend to support natural gas demand and prices. El Niño events can produce milder winters and suppress heating demand. Climate scientists and energy market analysts invest heavily in forecasting these phenomena months in advance because their implications for natural gas demand - and therefore prices - can be substantial.

For Indian traders working with MCX natural gas futures, maintaining awareness of the U.S. weather outlook - particularly heading into the October-to-March heating season - is as important as monitoring domestic Indian factors. The weekly EIA natural gas storage report, released every Thursday at 10:30 AM Eastern Time (typically 10:00 PM IST), is the most important recurring data release for natural gas markets and frequently produces price swings of 2-5 percent or more in a matter of minutes.

Key Price Drivers: Production, Storage, and LNG Exports

While weather dominates short-term natural gas price moves, the structural supply-demand balance - driven by production volumes, storage levels, and increasingly LNG export demand - determines the medium-term price trend.

U.S. dry natural gas production has grown dramatically over the past two decades, driven by horizontal drilling and hydraulic fracturing (fracking) technologies that unlocked enormous reserves in shale formations. Total U.S. production, which stood at around 20 trillion cubic feet (TCF) per year in the early 2000s, has grown to over 35 TCF per year, making the United States the world's largest natural gas producer. This supply surge has structurally kept Henry Hub prices lower than they would otherwise be, and has at times pushed prices to multi-decade lows.

However, U.S. production is not perfectly elastic. Below certain price thresholds, producers reduce drilling activity, leading to a lagged decline in supply that eventually supports prices. The relationship between the natural gas rig count (tracked weekly by Baker Hughes) and subsequent production levels is a closely watched indicator. When active gas rigs decline significantly, analysts begin forecasting production plateaus or declines roughly six to twelve months into the future.

Underground natural gas storage in the U.S. is the key buffer between production and consumption. Storage levels are reported weekly by the EIA and compared against five-year historical averages. When storage is significantly below the five-year average - as it was in early 2022 heading into summer - it signals a tighter market that cannot absorb unexpected demand surges as easily, supporting higher prices. When storage is well above average, it typically weighs on prices by suggesting ample supply cushion.

LNG exports have increasingly become a critical demand driver that competes with domestic U.S. consumption for available gas. U.S. LNG export capacity grew from near-zero in 2015 to over 13 billion cubic feet per day (Bcf/d) by the mid-2020s, making the U.S. the world's largest LNG exporter. When international LNG prices (JKM or TTF) are high relative to Henry Hub, it incentivises maximum throughput at U.S. export terminals, drawing more gas from domestic supply and tightening the domestic market. When an export terminal suffers an outage - as happened with the Freeport LNG facility in 2022, which was forced offline for several months - the resulting supply glut in the domestic U.S. market pushed Henry Hub prices sharply lower.

For Indian traders, LNG export terminal news and international LNG price spreads are therefore highly relevant inputs. An unexpected outage at a major U.S. LNG export facility can have an almost immediate bearish effect on Henry Hub prices and, through the benchmark linkage, on MCX natural gas prices. Conversely, strong Asian LNG import demand - whether driven by an unusually hot summer, nuclear outages, or hydro-power shortfalls - can pull U.S. exports higher and tighten the domestic U.S. market, supporting Henry Hub and therefore MCX prices.

Understanding Natural Gas Volatility: Why Prices Move So Sharply

Natural gas is widely acknowledged as one of the most volatile commodities in the world. Annual price ranges of 50 to 100 percent from low to high are not unusual; in exceptional years like 2022, prices moved even more dramatically. Understanding the structural reasons for this volatility is essential for anyone approaching this market.

The first and most fundamental source of volatility is demand inelasticity combined with supply rigidity over short time horizons. When a cold snap hits and heating demand spikes, consumers cannot simply switch off their furnaces or quickly find alternative energy sources. Demand must be met from storage and production that are essentially fixed in the short run. This inelastic demand meeting an effectively inelastic short-run supply creates price spikes that can be extreme and rapid.

The second source of volatility is weather forecast uncertainty. Markets price in the expected weather, and forecasts change multiple times daily. A revision in a five-day weather model from an expected cold front to milder temperatures can move natural gas futures by several percent within minutes as traders reprice expected demand. This sensitivity to forecast changes means natural gas futures can make large moves on days with no "news" in the traditional sense - simply a model revision in an atmospheric forecast.

The third source of volatility is the storage level relative to normal. When storage is very low, the market has little buffer. Every cold week, every unexpected demand increase, every production disruption hits an already tight system and produces an outsized price response. Conversely, when storage is very high, prices can be suppressed for extended periods and respond tepidly to bullish news. This non-linearity - where price sensitivity to the same demand shock varies enormously depending on the storage backdrop - is a key characteristic that experienced natural gas traders monitor closely.

The fourth source is the market's relatively low liquidity compared to crude oil. While the CME Henry Hub futures contract is actively traded, it is much smaller in notional value terms than crude oil markets, meaning that large institutional positions can move prices more significantly. During low-liquidity periods - holiday sessions, overnight trading, or immediately before major report releases - the bid-ask spread widens and price gaps are more common.

For MCX traders in India, there is an additional layer of volatility introduced by the exchange rate. On days when both the USD/INR rate and the Henry Hub price move significantly, MCX natural gas can produce intraday swings that exceed what either factor alone would suggest. This compounding of commodity volatility and currency volatility is one reason why natural gas on MCX is considered a sophisticated, high-risk instrument unsuitable for inexperienced traders without appropriate risk management.

Historical data shows that natural gas futures regularly experience daily price changes of 3 to 5 percent, and during particularly active periods - major EIA storage surprises, sudden weather pattern changes, or geopolitical disruptions - daily moves of 8 to 15 percent are not unprecedented. This is sharply higher than the typical daily volatility of equity indices or even of crude oil, making position sizing and stop-loss discipline absolutely critical.

The Role of the EIA Weekly Storage Report

Among all the data releases that move natural gas prices, the U.S. Energy Information Administration (EIA) weekly natural gas storage report stands apart in its consistency and market impact. For any serious participant in natural gas markets, understanding this report is non-negotiable.

The EIA publishes the report every Thursday at 10:30 AM Eastern Time (approximately 9:00 PM or 10:00 PM IST, depending on the time of year and U.S. daylight saving). The report details the net change in working natural gas held in underground storage facilities across the U.S. during the previous week. The figure is broken down into three regions - East, Midwest, and South Central - as well as a Pacific region and a Mountain region, but the headline "total working gas in underground storage" and the weekly net change relative to analyst consensus expectations are what move markets.

Markets form a consensus expectation before the release, aggregated from surveys of analysts and traders. The actual reported figure is compared to this consensus, and the deviation - the "storage surprise" - drives the price reaction. If the consensus expected a storage draw of 100 billion cubic feet (Bcf) and the actual draw was 130 Bcf, the larger-than-expected draw signals tighter supply and is bullish for prices. If the actual draw was only 70 Bcf, the smaller draw is bearish.

The size of the price reaction depends not only on the magnitude of the surprise but also on where storage levels stand relative to the five-year historical average. When total storage is already well below the five-year average, a bullish storage surprise (larger draw or smaller injection than expected) can trigger very sharp price spikes because the market sees the buffer shrinking further. In contrast, the same surprise magnitude when storage is well above average produces a muted reaction.

For Indian traders who cannot always be at their screens at 10:00 PM IST on Thursdays, this creates both opportunity and risk. The post-report period is one of the highest-volatility windows in the entire natural gas trading week, and prices can move 2 to 5 percent within minutes of the release. Orders placed before the release may be filled at prices far from expectation if a large surprise occurs. Using limit orders rather than market orders, or abstaining from holding open positions through the release unless intentionally positioned for the volatility, are prudent practices.

Seasonal patterns in storage are also tradeable. During the injection season (typically April through October), the market monitors whether weekly injections are keeping pace with what is needed to reach adequate storage levels by the start of the winter heating season. If the pace of injections is running behind historical norms, it sets the stage for a tighter supply situation in winter and supports prices even in the shoulder season. Tracking cumulative storage versus the five-year average trajectory is a key part of any fundamental natural gas analysis framework.

Natural Gas Futures Curve: Contango, Backwardation, and Seasonality

Unlike equity markets, where you typically observe a single current price for a stock, commodity futures markets display a "futures curve" - a series of prices for contracts expiring at different points in the future. The shape of this curve tells a great deal about current market conditions, and natural gas displays some of the most distinctive and predictable curve shapes of any commodity.

When the futures curve slopes upward - that is, contracts for delivery further in the future are priced higher than near-term contracts - the market is said to be in "contango." When the curve slopes downward - nearer-term contracts are more expensive than later ones - the market is in "backwardation." For natural gas, however, the relevant concept is slightly more nuanced because the curve is heavily influenced by seasonal demand patterns, not just simple supply-demand tightness.

A typical natural gas futures curve in a normal supply environment will show a pronounced seasonal pattern: prices dip in spring and autumn (shoulder seasons of low demand), rise into summer (cooling season), dip again in early autumn, then spike sharply for the winter months (November through March) when heating demand peaks. This seasonal "hump" pattern in the curve reflects expected demand variations throughout the year.

When winter prices are significantly higher than summer prices, it creates a "winter premium" in the forward curve. The existence of this premium incentivises storage operators to buy gas in summer, inject it into storage, and implicitly sell it forward at the higher winter price - a classic storage arbitrage. As storage capacity fills and traders exploit this arbitrage, the spread between summer and winter prices narrows. When storage is very tight, the winter premium expands dramatically because the market needs to ration available supply and incentivise maximum injection activity.

For Indian traders working with MCX near-month contracts, the absolute level of the futures curve matters less than it does for a large natural gas producer or utility hedging multi-year production. However, understanding where in the seasonal cycle the market currently sits helps contextualise whether prevailing prices are at a seasonal high, a seasonal trough, or an anomaly relative to historical patterns.

The concept of "rolling" a futures position - closing the near-month contract as it approaches expiry and reopening in the next month - is relevant for those holding medium-term views. In contango, rolling a long position costs money because you sell the cheaper expiring contract and buy the more expensive next contract. In backwardation, rolling benefits the long holder. For natural gas, roll cost or roll yield varies enormously by season and market condition, and for those holding positions across multiple expiry cycles, this cost can add up significantly.

For a deeper exploration of contango and backwardation as structural concepts applicable across commodities, the Flattrade Learn article on contango and backwardation provides a more detailed treatment applicable to all commodity futures.

Geopolitical Drivers and Global Events Affecting Natural Gas Prices

While weather and storage dominate short-to-medium-term natural gas price movements, geopolitical events and structural global developments have increasingly become major price drivers, particularly following the energy crises of the 2020s.

The most dramatic illustration of geopolitics in natural gas pricing was the impact of the Russia-Ukraine conflict on European natural gas markets. Russia had historically supplied roughly 40 percent of Europe's natural gas, primarily through pipelines. When this supply was disrupted, European TTF prices spiked from under €20/MWh in 2020 to over €340/MWh at peak in August 2022. This was not an abstract headline for India: European buyers competing aggressively for LNG cargoes drove Asian LNG spot prices (JKM) to similarly historic levels, raising import costs for Indian LNG buyers and creating significant inflationary pressure in sectors like fertilisers and city gas distribution.

The ripple effects reached Henry Hub as well, though more modestly. U.S. LNG export facilities operated at maximum capacity to supply European and Asian buyers, reducing domestic U.S. supply availability and helping lift Henry Hub from multi-year lows to multi-year highs. MCX natural gas prices in India responded accordingly, though the combined effect of Henry Hub appreciation and Rupee depreciation made the INR-denominated price rise even more pronounced.

Middle East tensions, while more directly relevant to crude oil, also affect natural gas markets through several channels. Qatar, one of the world's largest LNG exporters, is a Gulf state, and any conflict escalation in the Persian Gulf creates risk of supply disruption for LNG shipments. The Strait of Hormuz, through which a substantial share of global LNG trade passes, is a critical chokepoint whose disruption would have severe consequences for Asian LNG importers including India.

Australian LNG labour disputes have historically caused sharp spikes in Asian LNG prices. Australia is one of the largest LNG suppliers to Japan, South Korea, and Taiwan, and any threat to supply from Australian facilities - whether through strikes, technical outages, or regulatory actions - immediately lifts Asian spot prices.

Climate policy developments also function as long-term structural price drivers. The global energy transition is simultaneously reducing demand for natural gas in power generation (as renewables expand) and increasing it in the medium term as a "bridge fuel" replacing coal. Policies that incentivise gas use over coal in India's power sector, or that delay the retirement of gas-fired capacity, are positive for domestic gas demand. At the same time, aggressive renewable deployment targets can cap the long-term demand outlook, creating uncertainty in the forward curve.

For Indian traders, maintaining broad awareness of these geopolitical and structural developments - without necessarily acting on every headline - helps contextualise whether a current price trend reflects temporary noise or a structural shift worth positioning around.

Taxation of Natural Gas Futures in India

Understanding the tax treatment of commodity futures profits and losses is as important as understanding the market itself. India's tax framework for commodity derivatives has specific provisions that every trader should be aware of, though the precise rates and thresholds are subject to change with each Union Budget, so always refer to the latest Finance Act and consult a qualified tax advisor.

Gains from commodity futures trading in India are treated as non-speculative business income for income tax purposes, provided the trading activity constitutes a business (which it typically does for active traders). Non-speculative business income is added to your total income and taxed at the applicable slab rate. This treatment is more favourable than speculative business income (applicable to intraday equity trading), which cannot be set off against non-speculative income.

Losses from non-speculative commodity futures trading can be set off against non-speculative business income from other sources in the same financial year. Any unabsorbed loss can be carried forward for up to eight assessment years and set off against non-speculative business income in those future years. This loss set-off and carry-forward provision is a meaningful tax planning tool for active commodity traders.

Goods and Services Tax (GST) is applicable on the brokerage and transaction charges levied by brokers and exchanges on commodity futures trades. The brokerage and exchange charges themselves are input costs for the trading business and are generally deductible as business expenses.

Securities Transaction Tax (STT) does not apply to commodity futures (it applies to equity and equity derivative transactions). However, Commodity Transaction Tax (CTT) is levied on non-agricultural commodity futures, including natural gas. CTT is a small levy applied on the sell side of commodity futures transactions and is a deductible expense for income tax purposes if the trading income is treated as business income.

For investors (as opposed to traders) who hold commodity positions infrequently, the characterisation of income as capital gains versus business income can be a grey area. Income tax authorities have generally taken the position that active futures trading constitutes business income rather than capital gains. Given the complexity of this determination, consulting a chartered accountant familiar with commodity taxation is strongly recommended.

Financial year for Indian income tax runs from 1 April to 31 March. All profits and losses from MCX natural gas trading during the financial year must be reported in your income tax return. The MCX and your broker provide transaction statements that facilitate accurate reporting. Maintain meticulous records of all trades, as the frequency and nature of commodity futures transactions makes accurate record-keeping both practically important and potentially required for scrutiny.

Please note that tax laws change with each Budget, and the rates, limits, and provisions described here are indicative. Always refer to the latest Finance Act and consult a qualified tax professional for advice specific to your circumstances.

Example

Key benefits

How it works

1. 1
   Open a Commodity Trading Account

   To trade natural gas futures on MCX, you need a commodity trading account with a SEBI-registered broker that is also an MCX member. This is linked to a demat account and a bank account for margin fund transfers.

2. 2
   Understand Contract Specifications

   Review the MCX natural gas contract details: lot size (1,250 MMBtu for standard, smaller for mini), price quotation (INR/MMBtu), expiry date, margin requirement, and settlement method (cash-settled against Henry Hub with USD/INR conversion).

3. 3
   Conduct Fundamental and Technical Analysis

   Assess U.S. natural gas storage levels versus the five-year average, weather forecasts, production trends, LNG export data, and the USD/INR exchange rate outlook to form a directional view. Complement this with price chart analysis to identify entry levels.

4. 4
   Define Your Trade Plan

   Before placing any order, set your entry price, stop-loss level, profit target, maximum holding period, and position size. Ensure the position size is appropriate given your total capital, with margin buffer well above the exchange minimum.

5. 5
   Place and Monitor the Trade

   Execute your order on the MCX platform through your broker's terminal. Monitor the EIA weekly storage report release on Thursdays, weather forecast updates, and any geopolitical or macroeconomic news that could affect prices.

6. 6
   Manage Mark-to-Market Margins

   MCX marks positions to market daily. If the position moves against you, additional margin may be required (margin call). Ensure you have adequate capital reserves to meet such calls without being forced to liquidate at an unfavourable price.

7. 7
   Close or Roll the Position

   Close the position when your target or stop-loss is hit, or roll it to the next month's contract if you wish to maintain exposure beyond the current expiry. Record the trade details accurately for tax reporting purposes.

Formula

MCX Natural Gas Price (INR/MMBtu) ≈ Henry Hub Price (USD/MMBtu) × USD/INR Exchange Rate
Storage Surprise = Actual EIA Reported Change (Bcf) − Analyst Consensus Expectation (Bcf)

Key takeaways

Frequently asked questions

Related terms