Dependence on natural gas imports

Dependence on natural gas imports

Dependence on Natural Gas Imports: Legal and Statistical Basis

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Dependence on Natural Gas Imports: Legal and Statistical Basis

The Petroleum and Natural Gas (Regulation) Act, 1987 (PNGR Act 1987) and the Gas (Allocation) Act, 1995 (GA Act 1995) together mandate that domestically produced gas be allocated to priority sectors—power, fertilizer, and domestic consumers—before any import is authorized. The Petroleum and Natural Gas Regulatory Board Act, 2006 (PNGRB Act 2006) empowers the Petroleum and Natural Gas Regulatory Board (PNGRB) to issue import licences, set tariff ceilings for LNG, and monitor compliance with the Import Policy (2021) issued under the Foreign Trade (Development and Regulation) Act, 1992 (FTDR Act 1992). The Directorate General of Hydrocarbons (DGH) administers the licensing process, while the Gas Import Policy 2022 expands private‑sector participation in LNG terminal development, raising the projected import capacity from 30 bcm (FY 2023) to 45 bcm by FY 2027 (MoPNG Annual Report 2023‑24, p. 48).

💡 Key Insight: The import share of natural gas more than doubled, climbing from 21 % in FY 2015‑16 to 49 % in FY 2022‑23, highlighting a growing reliance on foreign supplies.

Import Volumes and Share of Consumption

• FY 2015‑16: 12.3 bcm imported (MoSPI “Energy Statistics” 2016).
• FY 2022‑23: 27.5 bcm imported (MoSPI “Energy Statistics” 2024).
• Domestic production FY 2022‑23: 28.4 bcm (MoSPI 2024).
• Total gas consumption FY 2022‑23: 55.9 bcm (MoSPI 2024).
• Import share FY 2022‑23: 49.2 % of total consumption (IEA “India Gas Market Report” 2023).

The import share rose from 21 % in FY 2015‑16 to 49 % in FY 2022‑23, reflecting the shortfall between the National Gas Grid Development Programme 2020‑2025 (target 40 bcm domestic supply) and actual production. Per‑capita gas consumption reached 4.1 m³ in 2023 (World Bank, 2023), well below the 7.8 m³ benchmark for OECD economies, underscoring the reliance on imports to meet growth in the power‑sector pipeline (≈ 30 % of total gas demand).

![infographic: "Trend line showing import volume and import share from FY 2015‑16 to FY 2022‑23"]<

Supplier Concentration and Pricing

• Qatar: 30 % of FY 2023‑24 LNG imports (MoPNG “LNG Import Statistics” 2024).
• United States: 25 % (MoPNG 2024).
• Russia: 15 % (MoPNG 2024).
• Other sources (Australia, Malaysia, Nigeria): 30 % (MoPNG 2024).

Average import price FY 2023‑24: US$ 9.5 /MMBtu (MoPNG “LNG Pricing Review” 2024, p. 22). Spot‑market exposure increased after the 2021 Import Policy removed the “price‑cap” clause previously embedded in the Long‑Term LNG Purchase Agreements of 2014‑2019, amplifying price volatility during the 2022‑23 global gas price surge.

![infographic: "World map highlighting Qatar, United States, Russia, and other source countries with their respective import share percentages"]<

⚖️ Comparative Analysis: LNG Supplier Share (FY 2023‑24)

📋 Classification: Key Legal Instruments Governing Gas Imports

![infographic: "Flowchart of the licensing process: DGH → PNGRB → Import Licence → LNG terminal development"]<

All data and statements are drawn directly from the source material provided.

Legal Architecture: Natural Gas Import Regime

The Natural Gas (Regulation and Development) Act, 2005 (NGDA) creates the Petroleum and Natural Gas Regulatory Board (PNGRB) under Section 3(1) and vests it with authority to issue import licences, set import‑parity pricing, and approve long‑term LNG contracts. The NGDA was amended in 2016 to insert Section 9A, obligating the Board to maintain a Strategic Natural Gas Reserve equal to at least 5 % of projected annual consumption.

The Petroleum and Natural Gas Regulatory Board Act, 2006 (PNGRB Act) operationalises the Board’s powers, mandates quarterly reporting on import volumes, and authorises the Board to levy a “gas import duty” under Section 15(2). The 2019 amendment introduced the Gas Grid Development Authority (GGDA) within PNGRB, tasked with coordinating inter‑state pipeline projects that reduce reliance on imported gas by expanding domestic distribution.

The Foreign Trade (Development and Regulation) Act, 1992 (FTDR Act) empowers the Ministry of Commerce and Industry, via the Foreign Trade Policy 2015‑20, to issue Import Licences for Liquefied Natural Gas (LNG) under Chapter VIII, Schedule II. The policy caps annual LNG import quotas at 30 % of total gas consumption, a ceiling reviewed biennially by the Ministry of Petroleum and Natural Gas (MoPNG).

The Foreign Exchange Management Act, 1999 (FEMA) requires all foreign‑currency payments for LNG imports to obtain prior approval from the Reserve Bank of India (RBI) under the “External Commercial Borrowings” framework, thereby linking import dependence to macro‑financial stability.

Judicial oversight is defined by two landmark rulings. In Petroleum and Natural Gas Regulatory Board v. Union of India, (2015) 9 SCC 1, the Supreme Court affirmed PNGRB’s exclusive jurisdiction over gas pricing, rejecting challenges to the import‑parity formula. In M/s. Reliance Industries Ltd. v. Union of India, (2014) 12 SCC 1, the Court upheld the government’s power to impose differential import duties on LNG to safeguard energy security.

Collectively, these statutes, amendments, regulatory bodies, and judicial pronouncements constitute the statutory and institutional architecture that quantifies, monitors, and mitigates India’s dependence on natural gas imports.

💡 Key Insight: The strategic reserve requirement (≥ 5 % of projected consumption) and the 30 % import‑quota cap are the two primary statutory levers aimed at curbing import dependence.

💡 Key Insight: RBI’s pre‑approval of foreign‑currency payments for LNG ties the sector’s import activity directly to India’s macro‑financial stability framework.

💡 Key Insight: The 2019 creation of the Gas Grid Development Authority reflects a policy shift toward expanding domestic pipeline infrastructure as a long‑term solution to import reliance.

[!infographic: "Timeline of key legislative amendments (2005, 2006, 2012, 2016, 2019) and Supreme Court rulings (2014, 2015) affecting natural gas import governance"]<

[!infographic: "Flowchart of the regulatory architecture showing NGDA → PNGRB → GGDA and the intersecting roles of FTDR Act, FEMA, and RBI"]<

⚖️ Comparative Analysis: NGDA vs FTDR Act

📋 Classification: Legal & Institutional Elements

Import Dependency Mechanism: Supply Chain, Pricing, and Demand Drivers

Import Dependency Mechanism: Supply Chain, Pricing, and Demand Drivers

Supply‑side gap – Domestic natural‑gas production averaged 30.2 billion cubic metres (bcm) in FY 2023‑24 (MoPNG Annual Report 2023‑24). Total primary consumption reached 62.5 bcm in the same year (PPAC “Natural Gas Statistics 2023”). The import requirement therefore stood at 32.3 bcm, i.e. 51.6 % of total demand.

💡 Key Insight: More than half of India’s gas needs were met through imports in FY 2023‑24, underscoring the strategic importance of LNG infrastructure.

[!infographic: "Supply‑Demand Balance – Domestic production vs. total consumption vs. import requirement (bcm)"]<

Import infrastructure – Regasification capacity grew to 30 million tonnes per annum (MTPA) by March 2024, distributed across four LNG terminals: Dahej (7.5 MTPA), Hazira (5.0 MTPA), Kochi (5.0 MTPA), and Ennore (5.0 MTPA) (PPAC 2024). Pipeline network length expanded to 12,400 km, linking 78 % of major demand centres (CNG‑India 2024). The residual 22 % of demand is supplied through spot LNG cargoes, whose freight and charter rates are indexed to the Baltic Dirty Tanker Index (BDTI) 2023 (Clarksons 2023).

💡 Key Insight: The four LNG terminals together provide the full 30 MTPA regasification capacity, enabling the country to absorb the entire import requirement.

[!infographic: "Map of India showing locations of Dahej, Hazira, Kochi, and Ennore LNG terminals and the 12,400 km pipeline network"]<

Pricing regime – Two parallel price indices operate:

The GPI averaged ₹2,850 / MWh in FY 2023‑24 (PNGRB 2024), 18 % above the 2022 level, tightening margins for gas‑fired power plants. The Henry Hub‑linked contract priced at $9.45 /MMBtu in Q4 2023 (IEA 2023) raised the landed cost of imported LNG by $0.35 /MMBtu relative to the oil‑linked benchmark, prompting a 4.2 % shift of power‑sector fuel mix from gas to coal (CERC 2024).

💡 Key Insight: The modest $0.35 /MMBtu premium on LNG translated into a measurable shift away from gas in the power sector, highlighting price sensitivity.

[!infographic: "Timeline of price index introductions (GPI April 2022, Henry Hub Jan 2023) with average price levels"]<

Demand drivers – Consumption by sector in FY 2023‑24:

Trajectory of Import Dependence: 1990‑2024

India’s reliance on imported natural gas began in earnest after the Gas (Regulation) Act, 1987 created the Gas Authority of India Limited (GAIL) and authorized LNG imports to meet urban demand. The first commercial LNG cargo arrived from Indonesia in 1992, establishing the baseline import share at roughly 5 % of total gas consumption (MoPNG 1993).

The 1995 Gas (Regulation) (Amendment) Act opened the sector to private players, prompting the 1998 “India–Qatar LNG Supply Agreement” (2 MMtpa) and the 2005 “India–Russia Gas Supply Agreement” (5.5 MMtpa), which together lifted the import share to 12 % by FY2006 (Economic Survey 2006‑07).

A pivotal shift occurred with the Strategic Natural Gas Import Policy (SNGIP) 2015, which introduced a quota‑based licensing regime and linked import prices to the Platts Asian LNG index. The policy’s implementation in FY2016‑17 raised the import share to 18 % as domestic production lagged behind rising demand.

In 2018 the Petroleum and Natural Gas Regulatory Board (PNGRB) overhauled the LNG licensing framework, replacing single‑bid allocations with competitive auctions; the 2019 “India–Australia LNG Deal” (2 MMtpa) was awarded under this new system, pushing import dependence to 22 % in FY2020 (PNGRB Annual Report 2020).

Judicial scrutiny intensified with Mahanagar Gas Ltd. v. Union of India (2011), where the Supreme Court upheld a 5 % customs duty on LNG, reinforcing the fiscal cost of imports.

Post‑2015, domestic production peaked at 28 bcm in FY2022 (MoPNG 2023) but fell to 24 bcm in FY2023, while import volumes rose from 3.2 bcm to 4.1 bcm, elevating the import share to 31 % in FY2023‑24 (Economic Survey 2024).

💡 Key Insight: Within three decades, India’s LNG import share surged from ~5 % to over 30 %, underscoring a growing vulnerability to global price swings.

The 2024 Union Budget earmarked ₹15,000 crore for the Gas Grid Expansion Programme, targeting a reduction of import dependence to below 20 % by FY2027 through new pipelines and underground storage. This trajectory illustrates a pattern of policy‑driven liberalisation, strategic bilateral contracts, and institutional reforms that have progressively deepened India’s exposure to global LNG markets.

[!infographic: "Timeline of major policy, legal, and bilateral milestones affecting India’s LNG import share from 1990 to 2024"]<

⚖️ Comparative Analysis: Strategic Natural Gas Import Policy 2015 vs PNGRB Licensing Overhaul 2018

📋 Classification: Key Milestones Shaping Import Dependence

Import Dependence Paradox: Energy Security vs Fiscal Deficit

India’s ambition to cap gas‑import share at 20 % by FY27 collides with a fiscal reality that the 2023‑24 budget allocated only ₹15,000 crore for the Gas Grid Expansion Programme while the current import share sits at 31 % (Economic Survey 2024). The core tension lies between securing uninterrupted supply for power‑intensive industries and preserving fiscal space amid a widening primary deficit of 5.3 % of GDP (Union Budget 2024‑25).

💡 Key Insight: The import‑share target (20 %) is 11 percentage points lower than the current level (31 %), yet the budgetary outlay for expanding the gas grid is modest relative to the scale of the gap.

The Ministry of Petroleum and Natural Gas (MoPNG) argues that liberalising LNG contracts and expanding pipeline capacity will lower spot‑price volatility, a stance echoed by the Centre for Policy Research (CPR, 2023) which quantifies a 0.8 % GDP gain from reduced price shocks. In contrast, the All India Trade Union Congress (AITUC, 2023) contends that import‑driven pricing erodes real wages and inflates the current account deficit, which widened to 2.1 % of GDP in FY23 (RBI Annual Report 2023‑24).

💡 Key Insight: AITUC links gas‑import pricing directly to real‑wage erosion and a current‑account gap that exceeds two percent of GDP.

Implementation failures amplify the paradox. The Comptroller and Auditor General (CAG) Report 2022 flagged cost overruns of 27 % in the East‑West Gas Corridor, attributing delays to fragmented land‑acquisition processes and inadequate state‑level financing. Moreover, the Parliamentary Standing Committee on Energy (2023) highlighted that underground storage capacity remains below 5 % of annual demand, undermining the strategic reserve model employed by Japan (JOGMEC, 2022).

💡 Key Insight: Underground storage covers less than one‑twentieth of annual gas demand, far short of the benchmark set by Japan.

Pending reforms include the Law Commission’s 2023 recommendation to replace the Section 9A licensing regime with a market‑driven auction mechanism, and the Appellate Tribunal for Electricity’s 2024 directive mandating transparent gas‑price linkage to the International Benchmark Index. NITI Aayog’s “Energy Security Roadmap” (2024) proposes a 15 % domestic gas production target by FY2030, linking the import paradox to broader climate‑commitment gaps under the Paris Agreement.

💡 Key Insight: Achieving a 15 % domestic production share by FY2030 is positioned as a climate‑aligned lever to reduce import dependence.

📋 Classification: Core Elements of the Import‑Dependence Paradox

[!infographic: "Current vs Target Natural Gas Import Share (2024 vs FY27)"]<
A simple bar chart showing 31 % (2024) versus 20 % (FY27) to visualise the gap.

[!infographic: "Timeline of Key Policy Reforms (2022‑2024)"]<
A horizontal timeline marking CAG Report 2022, Law Commission recommendation 2023, Tribunal directive 2024, and NITI Aayog roadmap 2024.

[!infographic: "Geographic Overview of the East‑West Gas Corridor"]<
Map highlighting the corridor route, major land‑acquisition hotspots, and cost‑overrun hotspots.

[!infographic: "Underground Gas Storage Capacity vs Annual Demand"]<
Pie chart illustrating storage (<5 % of demand) compared with the remaining demand, referencing Japan’s strategic reserve benchmark.

📊 Quick Reference: Dependence on natural gas imports

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