LNG Netback & Global Arbitrage Lab

1. The Global Gas Revolution and US Gulf Coast Export Parity

Before the expansion of US shale gas liquefaction terminals (such as Sabine Pass, Corpus Christi, Freeport, Cameron, and Calcasieu Pass), global natural gas markets operated in isolated, regional silos governed by rigid, oil-indexed 20-year pipeline and LNG contracts. The introduction of destination-free US LNG contracts linked transparently to Henry Hub transformed liquefied natural gas into a fungible, globally traded commodity.

Under standard commercial tolling structures, the Free-On-Board (FOB) price of gas loaded onto an LNG vessel at the US Gulf Coast is governed by:

Here, the 115% multiplier compensates for pipeline fuel and gathering shrinkage required to transport gas from basins such as the Permian or Haynesville to the liquefaction facility, while $T_{\text{liquefaction}}$ represents the fixed capacity toll (typically $2.25 to $3.50/MMBtu) that reimburses the infrastructure owner's capital expenditure and operating expenses.

2. The Delivered Ex-Ship (DES) Netback Formula

In global energy markets, cargo buyers purchase LNG on a Delivered Ex-Ship (DES) basis, where the seller delivers the cryogenic liquid to the destination regasification terminal. The Netback Price is the effective FOB-equivalent dollar value realized at the loading jetty after subtracting all physical transportation costs:

Where cargo delivered volume accounts for operational Boil-Off Gas (BOG) losses during transit:

3. Cross-Basin Arbitrage Dynamics: TTF vs. JKM

Energy traders with flexible, destination-free volume continually evaluate the cross-basin arbitrage spread between Europe (governed by the Title Transfer Facility - TTF in the Netherlands) and East Asia (governed by the Japan Korea Marker - JKM assessment by S&P Global Platts):

When $\Delta_{\text{Arbitrage}} > 0$, Asia trades at an arbitrage premium, prompting traders to divert uncontracted cargoes toward Japan, South Korea, China, or Taiwan. However, because sailing to Asia via Panama requires ~50 days round-trip (and ~70 days via the Cape of Good Hope) compared to only 24 days to Europe, the trader must weigh the higher margin against tying up specialized vessel charter capacity for twice as long.

4. Project Finance & Liquefaction Debt Sizing

LNG export facilities require $5B to $15B+ in upfront capital expenditure per multi-train facility. To finance these megaprojects, developers secure non-recourse project debt sized to a target Debt Service Coverage Ratio (DSCR) of 1.35x to 1.50x. Because the facility earns fixed liquefaction tolling fees under 20-year Take-or-Pay contracts, the terminal's cash flows are shielded from commodity market fluctuations: