Building Around the Siege

China’s Infrastructure Answer to Washington’s Energy Coercion

On January 1, 2025, China’s first comprehensive Energy Law came into force. The State Council had published it the previous November with minimal ceremony, and it arrived without the press conference it probably warranted. The law defined hydrogen as a formal energy source for the first time, brought government-held and commercial crude stockpiles under a unified national reserve framework, and formalized the requirement that state companies maintain government-supervised emergency stocks under a new classification the law called “social responsibility” reserves. It entered the statute books two months before Operation Epic Fury opened in the Gulf, and approximately fourteen months before Washington’s energy strategists were declaring the war had cemented American control over global hydrocarbon supply.

The energy law did not cause any of that. What it did was codify an architecture that Beijing had been constructing, layer by layer, since at least 2003, when then-President Hu Jintao named a specific problem in a closed internal briefing that later entered the analytical public record: roughly 80 percent of China’s seaborne crude imports transited a single chokepoint, the Strait of Malacca, a 2.7-kilometer-wide passage that American naval doctrine could close within hours of a decision made in Washington. Hu called it the “Malacca Dilemma.” The phrase stuck. The two decades that followed were the attempt to engineer its resolution, not through military contest at the chokepoint itself, but through the patient, expensive, and largely undiscussed construction of supply routes, stockpiles, and consumption structures that the chokepoint could not reach.

The war that Washington hoped would lock the world into dollar-denominated American LNG contracts arrived, as Beijing’s planners had long anticipated it would, too late to stop the construction that was already two decades in.

The Reserve Calculation

China does not publish its strategic petroleum reserve figures. The National Development and Reform Commission manages the program through the Energy Reserves Office inside the National Food and Strategic Reserves Administration, and no quarterly report lands in any public database with a definitive barrel count. What exists is a reconstruction from import volumes, refinery run data, CNOOC and Sinopec storage capacity disclosures, and satellite imagery of tank farms at Zhenhai, Zhoushan, Huangdao, and Dalian, the four Phase I sites that were constructed from 2005 and filled by year-end 2009, storing approximately 103 million barrels. Phase II added roughly 200 million more barrels and was complete by 2019.

The United States Energy Information Administration’s April 2026 assessment, drawing on Vortexa Analytics, Argus Media, and Global Trade Tracker data cross-referenced against Chinese National Bureau of Statistics production and import figures, estimated that China’s total strategic inventory, combining government-held and commercial stocks, reached nearly 1.4 billion barrels by December 2025. Government-held reserves accounted for an estimated 360 to 401 million barrels, comparable to the American SPR’s 414 million barrels. Commercial reserves held by PetroChina, Sinopec, and CNOOC, brought under mandatory government supervision by the January 2025 Energy Law, added an estimated one billion barrels on top.

The accumulation rate tells the story more precisely than the total. Between January and August 2025, before the Gulf war opened, China was adding approximately 1.1 million barrels per day to its combined strategic stockpile, effectively pulling crude off the global market and into storage at a scale that, per EIA analysis, placed upward pressure on Brent prices and kept them in a relatively tight range around $68 per barrel through the second and third quarters. This was not passive: in mid-2024, the Chinese government had directed its national oil companies to add 59 million barrels to reserves by March 2025, and Sinopec and CNOOC were simultaneously building out at least 169 million barrels of new storage capacity across eleven sites scheduled for completion between 2025 and 2026. The January 2025 Energy Law removed the administrative distinction between the emergency reserve and the commercial stock, placing both categories under unified NDRC oversight and making the integration a legal fact rather than a policy preference.

At China’s import rate of roughly 11 million barrels per day, 1.4 billion barrels is approximately 127 days of supply. When Operation Epic Fury disrupted Hormuz flows in March 2026, Beijing’s refiners drew down commercial stocks. There was no emergency declaration, no announced IEA release, no scramble for spot cargoes. The buffer absorbed the shock in the time the diplomatic channels needed to run. Hu Jintao’s original problem, vulnerability to sudden supply interruption, had been addressed not by controlling the chokepoint but by extending the time horizon far enough that the chokepoint’s leverage dissolved.

The Overland Architecture

The reserve answers the short-term problem. The pipelines answer the structural one.

China’s Central Asia Gas Pipeline, running from Turkmenistan’s Galkynysh field, one of the largest gas deposits in the world with estimated reserves exceeding 26 trillion cubic meters, through Uzbekistan and Kazakhstan into Xinjiang, has operated since 2009 and now delivers 55 billion cubic meters per year through four parallel lines, the most recent of which, Line D, came online progressively between 2014 and 2020 despite significant construction complications on the Tajik and Uzbek segments. The financing was Chinese: China National Petroleum Corporation extended sovereign loans to Turkmenistan and Uzbekistan against the pipeline’s throughput, a structure that made both producing states clients of the Chinese gas transit system rather than independent suppliers capable of redirecting volumes to competing buyers. Turkmenistan, which holds the world’s fourth-largest gas reserves, sends 35 billion cubic meters per year to China under long-term contracts. It has no other viable export route. Russia blocked the northern corridor. Iran cannot absorb the volumes. The one direction Ashgabat’s gas can move at commercial scale is east.

This was not incidental. Chinese planners understood that securing overland supply was not only a matter of building pipes but of financing producer-state dependency on the Chinese route. The CNPC loan structures used across the Central Asia pipeline system were later applied in Myanmar, where the China-Myanmar Oil and Gas Pipeline, running from the Kyaukphyu deepwater port on the Bay of Bengal through 793 kilometers of Burmese territory into Yunnan Province, has delivered gas and crude oil since 2013 and 2015 respectively. The Myanmar pipeline bypasses the Malacca Strait entirely, delivering crude directly into China’s southwestern refining complex. Its strategic value has less to do with volume, roughly 200,000 barrels per day of oil capacity and 12 billion cubic meters of gas, than with geometry: it is the one existing crude import route that no interdiction of the Malacca Strait, the South China Sea, or the Taiwan Strait can interrupt.

The Russia corridor adds a different order of magnitude. Power of Siberia 1, originating at the Kovykta gas condensate field in Irkutsk Oblast and running 3,000 kilometers to the Heihe crossing into Heilongjiang Province, began commercial deliveries in December 2019 under a 30-year purchase agreement between Gazprom and CNPC at a price structure that, after nearly a decade of negotiation, was indexed to oil products rather than the European gas market. Gazprom delivered 31.12 billion cubic meters through the pipeline in 2024, reaching the annualized maximum contractual level of 38 billion cubic meters per year on December 1, 2024, a full month ahead of the scheduled milestone. In the first eight months of 2025, Gazprom’s gas exports to China grew 28 percent year-on-year as the company diverted volumes displaced from the European market. The September 2025 SCO summit agreement between Gazprom and CNPC raised the Power of Siberia 1 ceiling to 44 billion cubic meters, a revision requiring infrastructure investment on both sides of the border that the two companies committed to under the same meeting’s commercial accords.

Power of Siberia 2 is the project that completes the architecture. On September 2, 2025, Gazprom CEO Alexei Miller announced that CNPC and Gazprom had signed a legally binding memorandum of understanding on its construction, following talks between Xi Jinping and Vladimir Putin at the SCO summit in Beijing. The pipeline would run from Russia’s Yamal Peninsula in western Siberia, carrying gas from fields that once supplied Europe before the Ukraine sanctions collapsed that market, through eastern Mongolia into northern China, delivering 50 billion cubic meters per year under a 30-year supply agreement. Xinhua reported that Russia and China signed more than 20 cooperation agreements during the summit, with energy deals prominently among them. Miller placed the project’s cost at approximately $13.6 billion and confirmed that pricing terms would be negotiated separately.

The political economy of the signing was not disguised. By some estimates, completing the pipeline would allow Russia to offset nearly half the gas export revenue lost when European sales collapsed from 157 billion cubic meters in 2021 to a projected 39 billion in 2025. Moscow had been pushing for the deal for nearly a decade. Beijing had spent those years resisting, using Russia’s urgency to negotiate price terms below what Moscow’s European contracts had historically returned. The Wall Street Journal reported in June 2025 that Beijing’s position changed materially after the Iran war disrupted Qatari LNG supply and demonstrated the structural vulnerability of any import route transiting Hormuz. When Xi signed in September, CNPC and Gazprom had already struck an arrangement understood to price gas below the Asian oil-product basket indexation that Moscow had wanted. The asymmetry in official statements afterward made the negotiating outcome legible: Russian officials announced the MOU in detail, to Russian news agencies, at a press briefing. Chinese officials did not separately confirm it.

The Far Eastern Route, a third Russian-Chinese gas connection running through the Russian Far East to China’s northeastern provinces, delivers 10 billion cubic meters per year, with the September summit adding another 2 billion. When Power of Siberia 2 reaches full capacity, total Russian pipeline gas deliveries to China will exceed 106 billion cubic meters annually, more than Russia delivered to all of Europe in its largest years before the war.

None of these pipelines can be interdicted by a carrier strike group. None of them can be sanctioned out of existence without sanctioning CNPC, PetroChina, and Gazprom simultaneously, which would detach Germany’s remaining LNG contracts, Japan’s Arctic LNG 2 exposure, and a significant share of the global shipping market from the American-aligned financial system. The overland architecture is not a military deterrent. It is a supply diversification so geometrically distributed that any maritime interdiction strategy targeting it must also target the financial instruments of American allies to work.

The Production Floor

Beijing’s approach to domestic crude production between 2019 and 2025 is the clearest illustration of how a command economy applies capital to a strategic target without market justification. Global oil prices compressed investment incentives across the industry. Chinese state producers expanded anyway.

Xi Jinping issued explicit instructions in 2018 to increase domestic oil and gas exploration and production. What followed was the Seven-Year Action Plans for Enhanced Oil and Gas Exploration, covering 2019 through 2025, which directed CNPC, CNOOC, and Sinopec to increase upstream capital expenditure on a trajectory that was set by strategic necessity and not by price signals. CNOOC, whose domestic exploration and production capital expenditure rose 4.6 times between 2016 and 2024 focused on Bohai Bay and South China Sea development, expanded output from roughly 690,000 barrels per day in 2020 to approximately 900,000 barrels by 2025, an increase of around 45 percent from 2021 levels. PetroChina, operating across the Ordos, Junggar, Tarim, Songliao, and Qaidam basins and investing in unconventional tight oil and shale developments, averaged 2.5 million barrels per day in 2025 and held approximately 1.2 million square kilometers of onshore acreage. Sinopec’s production, centered on the Shengli field in Shandong Province, stabilized after years of decline at roughly 696,000 barrels per day.

Total domestic production reached 4.3 million barrels per day by 2025, recovering from the 3.8 million barrel trough of 2018 and approaching the 4.4 million barrel level that Chinese fields produced at their 2015 peak before international price compression forced temporary cutbacks. Output is not commercially optimal at this level; the extraction costs in several Xinjiang and Sichuan tight oil plays exceed spot prices at which the volumes could be purchased on the open market. The government subsidizes the difference through state bank financing and transfer pricing within the NOC structure, because the strategic value of domestic supply independence at the margin is higher than the commercial loss on the barrel.

CNPC’s own research arm published a projection in 2025 that China’s crude oil consumption would peak that year. Sinopec’s forecasting division arrived at a similar conclusion, placing peak consumption in the 2025 to 2027 window. The NDRC and NEA’s guidance for the 15th Five-Year Plan, adopted in March 2026, targets peak oil consumption within the plan period running through 2030. These are not environmental commitments dressed as policy targets. They are demand forecasts from the state oil companies that buy and refine the oil, reflecting their read of the electrification rate now running through the transport sector and the industrial substitution program the NDRC has been promoting through its renewable energy substitution guidelines since October 2024.

The Yards

CSSC built a third of all the ships in the world in 2024. That figure, published by the Ministry of Industry and Information Technology and independently confirmed by Clarksons Research, describes a concentration of shipbuilding capacity that has no modern precedent. In 2024, Chinese yards received 74.1 percent of new global vessel orders, completed 55.7 percent of all global tonnage delivered, and held 63.1 percent of the global order backlog, marking the fifteenth consecutive year China led all three indicators. New orders reached 113.05 million deadweight tons, a 58.8 percent year-on-year increase. The China Association of the National Shipbuilding Industry confirmed that during the 14th Five-Year Plan period from 2021 to 2025, all three metrics grew at rates that compressed the gap between Chinese yards and the combined output of every other shipbuilding country from competitive to categorical.

The specific data point that matters for any evaluation of the American SHIPS Act is not the aggregate market share but the product mix. Hudong-Zhonghua Shipbuilding, a CSSC subsidiary operating out of Shanghai, signed an order with QatarEnergy in April 2024 for 18 super-large LNG carriers of 271,000 cubic meters capacity, the largest single LNG carrier order ever recorded in the global shipbuilding industry. It added six more vessels from QatarEnergy in September 2024. As of mid-2025, Hudong-Zhonghua’s production schedule extended to 2030, and the company was planning to have 19 LNG carriers under simultaneous construction, a single-yard record. The LNG carriers that the SHIPS Act requires American LNG exports to travel on, from 2030, are being built to completion at a Chinese yard contracted through 2030. There is no American yard with the workforce, the dry dock capacity, the cryogenic system suppliers, or the accumulated LNG carrier construction experience to replace that production within the legislative timeline.

People’s Daily cited Yi Guowei, deputy manager of the large cruise ship project at CSSC’s Shanghai Waigaoqiao Shipbuilding, in April 2025: “the US used to be the world’s greatest shipbuilding power, but the shipbuilding industry requires a complete industrial chain, which took China decades to develop to reach its current scale.” Washington Post reporting from March 2025 quoted maritime experts describing the American revival aspiration as requiring decades of sustained government support, not a decade. US shipyards built 0.01 percent of global tonnage in 2024. The SHIPS Act’s target of 250 new US-flagged vessels over ten years is aspirational by any reading. The $5 per net ton port fee on Chinese-linked vessels will be collected and deposited into the Maritime Security Trust Fund while Chinese yards continue building at 67 percent of global new order volume. The fee does not interrupt construction. It finances a competitive response that, by the industry’s own structural logic, cannot reach commercial scale within the timeframe the legislation assumes.

In the green transition, the asymmetry accelerates further. Chinese yards received 78.5 percent of global new orders for green-energy vessels in 2024, per MIIT data published by CCTV, rising from 31.5 percent in 2021. This is not a consequence of subsidy alone. It reflects accumulated engineering capability in dual-fuel LNG systems, methanol propulsion, and hull design optimization that Korean and Japanese yards built over decades and that Chinese yards have since matched through a combination of reverse engineering, state-financed R&D investment, and a domestic order volume that generates the construction experience no training program can substitute for.

The Electrification Exit

The National Energy Administration’s data for 2024 is not primarily an environmental record. It is a strategic ledger.

China added 429 gigawatts of new electricity generating capacity in 2024, a 21 percent increase over 2023, per NEA figures published in January 2025. Solar capacity grew 45.2 percent, adding 277 gigawatts to reach 887 gigawatts total. Wind grew 18 percent, reaching 521 gigawatts. The NEA’s own 2030 target for combined wind and solar capacity was 1,200 gigawatts, set by Xi Jinping in 2020 as an ambitious long-term goal. China met it in August 2024, six years ahead of schedule. The IEA’s World Energy Investment 2025 report, drawing on NEA production data, confirmed that China invested more than $625 billion in clean energy in 2024, nearly doubling its 2015 level and accounting for 31 percent of total global clean energy investment. By August 2025, total installed renewable capacity exceeded 1,600 gigawatts, surpassing fossil fuel capacity for the first time. The China Electricity Council reported in February 2026 that clean electricity capacity had reached 52 percent of total installed capacity.

These numbers describe an electricity system in structural transformation, but the strategic significance is in the demand side, not the supply side. Every gigawatt of renewable electricity deployed domestically replaces a volume of imported fuel that would otherwise need to transit the Malacca Strait or the Hormuz corridor. The NDRC’s October 2024 Guiding Opinions on Promoting Renewable Energy Substitution made the substitution logic explicit: fossil fuels were to be replaced systematically in industrial, transport, and residential applications, with the electrification rate of terminal energy consumption reaching 30 percent by 2025. The NEA and NDRC’s joint Action Plan for Accelerating the New Type Power System, released in August 2024, set a construction schedule through 2027 for the grid modernization and storage infrastructure needed to absorb the renewable output without the curtailment losses that had been running at above ten percent in peak generation periods. State Grid Corporation of China committed a record $88.7 billion in grid investment for 2025, an increase from the $84.7 billion spent in 2024. Battery storage investment rose 69 percent from the first half of 2024 to the first half of 2025 alone.

Transport is where the pace most visibly outstrips the government’s own projections. The China Association of Automobile Manufacturers reported that new energy vehicle sales in 2024 reached 12 million units, a 40.9 percent market share, beating the government’s 40-percent-by-2030 target six years early, per Xinhua’s citation of the data. By March 2025, NEV market penetration hit 51.1 percent of all new passenger vehicle sales, driven by trade-in programs and continued purchase tax exemptions. In the first half of 2025, NEV sales reached 50.1 percent of the market, the first calendar half-year where electric vehicles collectively outsold internal combustion vehicles in China. The IEA’s 2025 Global EV Outlook projected that China’s sales share would reach approximately 80 percent by 2030, on current policy trends. A 2025 study by the Rhodium Group, drawing on fleet composition and fuel economy data, estimated that China’s EV fleet had already displaced more than one million barrels per day of national oil demand by 2025.

The trajectory that these figures describe has a specific geopolitical implication that is rarely stated in the Western energy security literature. The Combustion Mandate’s coercive mechanism depends on the existence of a sufficiently large Chinese import requirement to exercise leverage over. As long as China imports 11 million barrels per day, it remains vulnerable to supply disruptions, premium pricing, and the financial infrastructure of the dollar-denominated commodity market. Every barrel per day of oil that Chinese industry or transport stops consuming is a barrel of leverage the Combustion Mandate loses. CNPC’s projection of a 2025 consumption peak, if correct, means the leverage window is not measured in decades. It may already be closing. Beijing is not simply building alternative supply to replace American-controlled LNG. It is attempting to exit the hydrocarbon import dependency before that dependency can be converted into a structural lock-in of the kind the SHIPS Act and the LNG terminal contracts are designed to produce.

The Settlement Infrastructure

The People’s Bank of China’s Cross-Border Interbank Payment System processed the equivalent of $245 trillion in yuan-denominated transactions in 2025, per Atlantic Council GeoEconomics Center analysis of CIPS public filing data. The figure is not primarily significant as a dollar comparison. CIPS remains far smaller than SWIFT-CHIPS by network reach, and the BIS 2025 Triennial Central Bank Survey found the dollar present in 89.2 percent of all foreign exchange transactions. What CIPS represents, and what a transaction infrastructure of that scale demonstrates, is that yuan-denominated settlement of energy and commodity trade is operationally viable at volume, not experimental.

The March 2026 Hormuz disruption provided a stress test. As the crisis deepened, daily transaction volume on CIPS rose from a range of $85 to $105 billion to above $130 billion, reaching a daily average of $134 billion for the month, a figure CIPS itself published on April 1, 2026. The spike corresponded to increased yuan-denominated commodity settlement as buyers and sellers sought to route transactions outside the dollar clearing infrastructure that Washington had repeatedly demonstrated it could weaponize through secondary sanctions. Iran was charging Hormuz transit tolls in yuan. China was buying over 80 percent of Iran’s seaborne oil exports through PRC commercial banks, with payments handled in yuan at terms that made the cargoes commercially attractive despite the sanctions environment, per Atlantic Council analysis of CIPS and shipping data.

The mBridge platform, developed by the PBOC in partnership with the Hong Kong Monetary Authority, the Central Bank of the UAE, and the Central Bank of Saudi Arabia, had processed more than 4,000 transactions worth $55.49 billion by early 2026, with 95.3 percent denominated in China’s digital yuan. Saudi Arabia’s central bank joined CIPS as a full participant in June 2024. In November 2025, the UAE executed its first government payment through the wholesale digital dirham on mBridge, a test of readiness for energy and commodity settlement at the central bank level. In October 2023, PetroChina International had completed the first cross-border crude oil settlement in digital yuan, purchasing one million barrels through the PBOC’s e-CNY platform, and PBOC officials described the transaction as a pilot for extending yuan settlement systematically to commodity procurement.

Cross-border yuan settlement in the first three quarters of 2025 reached 13 trillion yuan, approximately $1.85 trillion, accounting for 39 percent of China’s goods trade over that period, per Oxford Economics analysis cited by the South China Morning Post. That figure was four times the level of 2017, before the first US-China trade war. China’s own Treasury holdings had fallen below 1 percent of its foreign reserves by 2025, per State Administration of Foreign Exchange data, from roughly 40 percent of reserves circa 2010. Russia had shifted the bulk of its energy transaction settlement with China to yuan and ruble. Arctic LNG 2, whose construction Chinese enterprises supplied with critical components, had delivered at least 21 LNG shipments to China on vessels under US sanctions by late 2025, per Congressional Research Service reporting on customs and shipping records.

None of this displaces the dollar. The IMF COFER data showed the dollar’s share of global foreign exchange reserves at 56.3 percent as of the second quarter of 2025, down from 58.9 percent in 2020. The direction of movement is clear. The pace is not. What the CIPS and mBridge architecture provides is not a replacement system but an escape valve: the operational capacity to route a meaningful share of energy trade outside dollar settlement when American sanctions pressure makes the dollar channel prohibitively expensive. A transaction architecture that diverts even 30 to 40 percent of China’s energy procurement out of dollar settlement erodes the Combustion Mandate’s financial reinforcement mechanism without requiring a reserve currency transition that would take decades.

The Race’s Real Terms

The standard framing of the China-America energy contest is military: carrier strike groups versus anti-access systems, Blue Water versus A2/AD, the South China Sea versus the second island chain. That framing is largely irrelevant to the question being decided. China commissioned one catapult-equipped carrier, one large amphibious assault ship, at least seven destroyers, and six frigates in 2025, per Maritime Executive data compiled from CSSC construction records. Its naval buildout is substantial and accelerating, but it is designed for Taiwan Strait deterrence and Western Pacific contingency, not for reopening a strait in the Persian Gulf under fire from American carrier aviation. Beijing does not need to contest the Gulf militarily to defeat the Combustion Mandate’s strategic logic.

The contest is temporal. Washington’s strategy requires locking importing countries into long-term dollar-denominated LNG contracts before China’s overland pipelines, domestic renewable capacity, and EV fleet reduce the leverage those contracts represent. The lock-in timeline is the early 2030s, when American LNG terminal capacity is projected to double under the build programs already permitted. China’s timeline, by CNPC’s own internal research, places the peak of its hydrocarbon import dependency in 2025, with consumption declining structurally from that point as electrification accelerates through the transport and industrial sectors.

The gap between those two timelines is where the entire strategic wager is made. If American LNG terminal capacity comes online in 2030 and 2031, and China’s oil demand has already peaked and begun declining, the buyers that American energy majors need to fill those terminals are not locking into thirty-year contracts. They are hedging, renegotiating, or redirecting toward the Power of Siberia network and the growing yuan-settled spot market that CNPC and China’s independent refiners are already operating. The SHIPS Act’s LNG carrier requirement becomes irrelevant if the cargo volumes are not there to justify the fleet. The Maritime Security Trust Fund finances yards whose strategic rationale depends on LNG export demand that the electrification curve is actively eroding.

Coal still generates approximately 60 percent of China’s electricity by output despite clean electricity’s majority in installed capacity. The electrification of heavy industry, steel, cement, and petrochemicals, runs on a longer investment cycle than the electrification of passenger vehicles. Power of Siberia 2’s Chinese segment construction timeline has not been disclosed. These are the genuine uncertainties in Beijing’s program, and its planners know them. The 15th Five-Year Plan was not built on the assumption that everything goes according to schedule.

It was built on the assumption that Washington’s strategy has a narrowing window, and that window can be closed before it closes around China.