Natural Gas Trading Journal

Natural gas is one of the most volatile commodity markets available to retail traders, with Henry Hub spot prices capable of swinging 10–20% in a single session during winter demand spikes or supply disruptions. The front-month /NG futures contract on CME is a pure expression of US supply/demand balance — and that balance is reset every Thursday morning when the EIA releases its Weekly Natural Gas Storage Report. For traders in this market, a natural gas trading journal is not optional discipline — it’s the primary tool for turning weather forecasts and storage data into measurable edge.

Key Statistics

Metric	Value	Source
Henry Hub Range (2022–2024)	$1.50–$9.00/MMBtu	CME Group / EIA
/NG Contract Size	10,000 MMBtu	CME Group
P&L per $0.10 Move	$1,000 per contract	CME Group
EIA Report Release	Thursdays 10:30 AM ET	U.S. EIA
LNG Export Demand	~14 Bcf/day	EIA 2024
50 Bcf Storage Surprise	~3–5% price move in minutes	CME historical data

The $1.50–$9.00/MMBtu range across 2022–2024 — from a summer 2023 glut to the August 2022 Freeport LNG disruption peak — is one of the widest two-year commodity ranges on record. This regime-dependence means strategies that worked in a $6+ environment can produce systematic losses in a $2 glut. Tracking which price regime was active at every trade entry is not optional — it’s foundational.

Trading Hours

Session	Open	Close	Timezone
CME Globex (Sun–Fri)	18:00	17:00 (next day)	ET
Daily Maintenance Halt	17:00	18:00	ET
EIA Report Window	10:15	11:00	ET (Thursdays only)

The single most important recurring window is Thursday 10:15–11:00 AM ET. The EIA report drops at 10:30 AM; the 15 minutes before and 30 minutes after represent the highest-volatility, highest-volume period of the nat gas week. Traders who are not journaling this window specifically are leaving their most actionable performance data unmeasured.

Popular Instruments

Futures (CME)

• /NG front-month — the benchmark contract; 10,000 MMBtu, CFTC-regulated, liquid during US hours
• Calendar spreads (Jan/Feb winter strips) — the spread between prompt delivery and winter contracts quantifies the market’s storage risk premium; widening spreads signal tightening supply
• /NG options — used to measure implied volatility; nat gas IV regularly reaches 60–100%+ annualized during winter

ETFs

• UNG (United States Natural Gas Fund) — tracks front-month /NG; subject to roll decay but accessible without futures account
• BOIL / KOLD — 2x leveraged long/short ETFs; useful for short-term tactical bets but decay rapidly in choppy regimes

CFDs

• IG Group, Saxo Bank, CMC Markets — micro-size exposure with wider spreads; suitable for traders outside US futures markets but requires careful spread-adjusted P&L tracking in the journal

Popular Brokers

Broker	Import to JournalPlus	Notes
Interactive Brokers	Supported	Full /NG futures history via CSV
NinjaTrader	Supported	Direct integration for CME futures
TradeStation	Supported	Futures and options data
IG Group	Manual entry	CFD platform; no direct import
Saxo Bank	Manual entry	CFD and futures; export CSV for manual log

For CFD traders on IG or Saxo, the most practical approach is exporting trade history weekly and logging the EIA consensus/actual fields manually in JournalPlus custom fields — this preserves the catalyst data that automated imports would miss anyway.

Challenges & Solutions

EIA Report Volatility Spikes

The weekly EIA storage report routinely moves /NG 3–5% in the first 5 minutes after release. Traders who don’t record the consensus estimate at entry have no baseline to evaluate whether their reaction trade was disciplined or simply lucky. A storage surprise of 50 Bcf vs. consensus — not uncommon in winter — can trigger moves that exceed a full day’s normal range.

Solution: Add three mandatory fields to every Thursday trade — consensus Bcf, actual Bcf, and the surprise magnitude (actual minus consensus). After 20 reports, filter by surprise magnitude and calculate your expectancy at different deviation thresholds. This is how you discover whether you have a genuine EIA edge.

Seasonal Regime Confusion

Mean-reversion strategies that produce consistent profits during injection season (April–October, storage builds) can generate systematic losses during withdrawal season (November–March), and vice versa. Natural gas is historically weakest in April–May as storage refill begins, and strongest in January at peak heating withdrawal. Without regime tagging, a trader cannot separate strategy performance from seasonal beta.

Solution: Tag every trade as “injection” or “withdrawal” season. Run a seasonal performance filter quarterly. If your win rate differs by more than 15 percentage points between regimes, you have a regime-dependent strategy — which means you should only activate it in the regime where it works.

Weather Forecast Sensitivity

Natural gas prices react to temperature forecasts 6–14 days forward, not today’s conditions. Logging a note like “cold weather expected” is operationally useless. What matters is the specific HDD anomaly — for example, a NOAA forecast showing the Midwest/Northeast running +15 HDD above the 30-year normal in the 8-day window. Institutional nat gas desks track the HDD/CDD deviation as a primary signal; retail traders who don’t log the same data can’t backtest against institutional behavior.

Solution: Record the NOAA 6-14 day HDD anomaly figure (available free at weather.gov) at the time of trade entry. A deviation of 10+ HDD from the 30-year normal is the widely-watched institutional trigger. Over time, correlate your P&L with HDD deviation thresholds to find where your weather-driven trades have positive expectancy.

LNG Export Disruption Blindspots

US LNG export terminals — Freeport, Sabine Pass, Calcasieu Pass — collectively process roughly 14 Bcf/day of US production. A single facility outage can materially shift the supply/demand balance. The Freeport LNG shutdown in June 2022 contributed to Henry Hub reaching $9.00/MMBtu. Traders who don’t log whether an LNG event was a factor in their entry cannot later distinguish their fundamental thesis from noise.

Solution: If an LNG export facility outage or restart influenced your entry, log the facility name, estimated capacity offline (in Bcf/day), and the expected duration. This creates a dated record of your fundamental thesis — and lets you evaluate whether you correctly assessed the magnitude of supply impact.

Volatility Regime Mismatch

Nat gas implied volatility swings from 40% annualized in calm summer regimes to 100%+ during polar vortex events. Position sizing rules calibrated for 45% IV become dangerous at 90% IV — the same stop distance represents twice the expected daily range. A journal without IV data at entry makes this pattern invisible.

Solution: Record implied volatility at entry (from CME /NG options) and flag trades as “elevated IV” (above 65%) or “compressed IV” (below 45%). Filter your results by this flag. If your average R is lower in elevated IV environments, reduce position size when IV is high — and document the rule change in your trading plan.

Journaling Tips for Natural Gas

Log the full EIA data set on every Thursday trade. The minimum viable data set is: consensus Bcf estimate, actual Bcf print, surprise magnitude, and your entry/exit times relative to the 10:30 AM release. Optional but high-value: log whether you were positioned pre-report or entered post-release, since these two approaches typically have opposite risk profiles.

Quantify the weather catalyst. Every weather-driven trade should include the NOAA 6-14 day HDD or CDD anomaly at entry. “Polar vortex incoming” is a narrative — “+15 HDD above 30-year normal, Midwest/Northeast, days 6–12” is a data point you can analyze.

Track the Jan–March spread at entry. The spread between the front-month /NG contract and the January or February deferred contract is a real-time measure of storage risk premium. A widening spread suggests the market is pricing in tighter-than-expected winter supply — log it as a market context field alongside your entry price.

Review your EIA trades separately from non-EIA trades. Filter your journal monthly and compare win rate, average R, and maximum adverse excursion between EIA-window trades and other trades. Many nat gas traders discover their edge is concentrated entirely in one category — and that the other is diluting overall performance.

Key Metrics to Track

• EIA storage surprise (Bcf) — actual print minus consensus; your primary catalyst quantifier
• NOAA HDD/CDD deviation — 6-14 day anomaly vs. 30-year normal at trade entry
• Seasonal regime — injection (April–October) or withdrawal (November–March)
• Implied volatility at entry — from CME /NG options; flag elevated vs. compressed
• Front-month vs. Jan strip spread — storage risk premium at entry
• P&L per MMBtu and per contract — standardized unit for cross-trade comparison
• Catalyst type — pre-EIA weather play, post-EIA reaction, LNG export news, NOAA revision
• Stop distance in MMBtu and dollars — mandatory for consistent sizing ($0.17 × 10,000 × contracts)
• Time-in-trade relative to EIA release — entry and exit timestamps on Thursdays
• Contract month traded — front-month vs. deferred; basis risk differs materially

How JournalPlus Helps

JournalPlus supports custom fields at the trade level, which is the feature nat gas traders need most. The EIA consensus/actual fields, HDD anomaly, seasonal regime tag, and LNG event flag are not standard brokerage data — they must be logged manually. Custom fields in JournalPlus let traders build a structured data schema around the Thursday EIA report and weather catalysts, then filter and analyze by those fields across any date range.

For futures traders importing from Interactive Brokers or NinjaTrader, trade history loads automatically — execution data is populated without manual entry, leaving the trader to focus on the fundamental catalyst fields that a futures trading journal can’t auto-populate from brokerage data. The separation of execution data (auto-imported) from fundamental context (manually logged) is the right architecture for nat gas, where both layers are essential.

Consider the example scenario that illustrates the value of this approach: on a Wednesday evening in January, NOAA’s 6-14 day forecast shows a polar vortex delivering temperatures 12°F below normal across the Midwest and Northeast — a +15 HDD anomaly vs. the 30-year average. Thursday’s EIA consensus on Investing.com shows -182 Bcf withdrawal expected. A trader goes long 2 /NG contracts at $3.45/MMBtu with a stop at $3.28 — risk of $0.17 × 10,000 × 2 = $3,400. The EIA print comes in at -201 Bcf, 19 Bcf larger than expected — price spikes to $3.82. The trader exits at $3.78 for a $0.33/MMBtu gain ($6,600 gross, $3,200 net). In JournalPlus, they log: EIA consensus -182, actual -201, HDD deviation +15, entry catalyst “pre-report weather play,” exit catalyst “EIA beat, partial retracement from spike high.” After 20 such trades, filtering by “pre-report” vs. “post-EIA reaction” reveals which timing approach has higher expectancy — the kind of insight that no generic commodities trading journal template provides.