Iran–Pakistan Gas Pipeline and Gas Sector Analysis: Indigenous Gas, Gas Market Liberalization, and the Feasibility of LNG and IP Pipeline Options for Pakistan’s Energy Security | June 2026

Iran–Pakistan Gas Pipeline • Gas Sector Analysis • June 2026

Iran–Pakistan Gas Pipeline and Gas Sector Analysis: Indigenous Gas, Gas Market Liberalization, and the Feasibility of LNG and IP Pipeline Options for Pakistan’s Energy Security

Domestic gas restoration • Gas market liberalization • LNG flexibility • IP pipeline feasibility tested on delivered cost and bankability

A strategic gas-sector analysis assessing Pakistan’s energy-security options through indigenous gas restoration, gas market liberalization, LNG portfolio flexibility, and the commercial feasibility of the Iran–Pakistan pipeline.

Core judgement: Pakistan’s gas-security strategy should be built on domestic supply restoration, LNG flexibility and market reform, not on a new imported-pipeline obligation. The Iran–Pakistan pipeline should be treated as a deferred diplomatic option, not as Pakistan’s base supply plan or a standby molecule. Its feasibility must be tested against future delivered local gas, future LNG, and the full plant-gate cost of Iranian pipeline gas, including price, financing, sanctions safety, winter deliverability, downstream offtake, FX exposure and circular-debt risk. Domestic gas remains strategically superior because it supports reserve replacement, producer liquidity, royalties, field services and lower import-fuel exposure; however, future incremental gas must be assessed on full delivered cost, not on legacy wellhead pricing alone.

Strategic domestic anchor

Indigenous gas restoration

Domestic gas is the core security molecule where it restores reserves, producer liquidity, industrial reliability and FX resilience.

Legacy Sui molecule

≈US$4/MMBtu reference

Low-cost legacy gas should be protected for efficient, high-value use, not used to suppress new field economics.

Incremental E&P / TPA

≈US$8/MMBtu where bankable

Higher-priced local gas can still be strategic where it revives reserves, supports producers and reduces import-fuel exposure.

Market reform spine

TPA + direct sales

Open access, direct E&P sales, transparent network charges and Sui transporter-seller separation convert supply into bankable demand.

Private LNG layer

Portfolio flexibility

Private LNG should provide balancing supply and price discovery where terminal access, credit terms and offtake are commercially secure.

Defensible LNG baseload

QP SPA-2 · 10.20%

The competitive contracted LNG layer; stronger than IP on flexibility, bankability and risk-adjusted delivered cost.

Price-review target

QG SPA-1 · 13.37%

High-cost legacy LNG layer; renegotiate, restructure or exit where contractual leverage is available.

IP pipeline option

IP · 0.12×JCC + US$1

before Pakistan-side pipeline, compression, financing and security costs and 750 MMCFD take-or-pay.

Plant-gate cost discipline

Pakistan-side adders

Pipeline capex, compression, security, taxes, FX, financing and take-or-pay exposure must be included before any fair comparison.

Sanctions and financing

Bankability first

Without a durable sanctions-safe framework, financing, insurance, EPC participation, payment channels and arbitration remain hard constraints.

Winter deliverability

Firm seasonal profile

Strategic value exists only if pressure, volume, winter delivery profile, penalties and shortfall remedies are verified and enforceable.

Final decision rule

Reform first, IP later

Build domestic gas, TPA, private LNG and Sui separation first; keep IP only as a deferred diplomatic option under strict commercial gates.

100%

Oil-Indexed Price Sensitivity — QP SPA-2, QG SPA-1 and Iran–Pakistan Formula

Oil benchmark	QP SPA-2 · 10.20% Brent	QG SPA-1 · 13.37% Brent	IP · 0.12×JCC + US$1	Commercial reading
US$60/bbl	US$6.12/MMBtu	US$8.02/MMBtu	US$8.20/MMBtu	QP remains the lowest-cost contracted LNG layer; IP is already above QG before Pakistan-side pipeline costs.
US$70/bbl	US$7.14/MMBtu	US$9.36/MMBtu	US$9.40/MMBtu	QG and IP move close to parity, but IP still carries additional infrastructure, sanctions and financing risk.
US$80/bbl	US$8.16/MMBtu	US$10.70/MMBtu	US$10.60/MMBtu	IP is only marginally below QG at molecule level, before plant-gate adders and bankability constraints.
US$90/bbl	US$9.18/MMBtu	US$12.03/MMBtu	US$11.80/MMBtu	QP remains clearly superior; IP remains conditional because delivered plant-gate cost would exceed the molecule formula.

Interpretation: QP SPA-2 is the defensible LNG baseload. QG SPA-1 is the high-cost legacy layer and should be the price-review target. IP should not be used as a negotiation proxy unless its price, sanctions, financing, winter deliverability and offtake risks are contractually reset. The IP column assumes JCC equals the listed oil benchmark for sensitivity purposes and excludes Pakistan-side pipeline, compression, financing, security, taxes and FX costs.

Why Iran–Pakistan Cannot Be the Base Plan — Current Position and Forward Feasibility Test

Test	Result	Why IP fails today
Supply need	FAILS	Pakistan’s binding constraint is not merely molecule availability. It is delivered affordability, producer liquidity, UFG exposure, fixed-cost recovery, circular debt, infrastructure utilisation and bankable demand. A new pipeline does not solve these constraints unless its price, utilisation and offtake are commercially bankable.
Delivered price	FAILS	IP must be compared against the forward delivered-cost stack, not only against today’s domestic gas or LNG prices. At current oil-indexed terms, IP has no clear advantage unless it is commercially rebased and tested against future local gas and LNG on a full plant-gate basis.
Demand bankability	FAILS	Demand is weak and price-sensitive; sanctioned industrial RLNG load materially exceeds actual consumption.
Reliability	FAILS	The pipeline has strategic value only if it can deliver firm seasonal volumes during Pakistan’s winter peak. Any revival must include verified pressure, volume, delivery profile, shortfall penalties and credible remedies for non-performance.
Sanctions / legal	FAILS	No project-specific sanctions waiver; Pakistan-side buildout, financing, insurance, payment channels and arbitration exposure remain hard bankability constraints.
Circular-debt risk	FAILS	Firm 750 MMCFD take-or-pay volumes without creditworthy offtake would migrate costs to consumers, SOEs or the federal budget.

8 Minimum Conditions Before Any IP Commercial Revival

Project-specific, durable and sanctions-safe execution framework.
Fundamental price reset to an LNG-competitive or capped hybrid benchmark.
Phased volumes only after financing, pipeline utilisation and downstream offtake are bankable.
Take-or-pay only after creditworthy downstream offtake is contracted.
Independent winter-deliverability certification with pressure, volume and shortfall-remedy obligations.
Ring-fenced cost recovery with no socialisation into existing circular debt.
Arbitration resolution, waiver or enforceable standstill on historic exposure.
Full integration with domestic reform: TPA, private LNG, UFG reduction, E&P liquidity repair and Sui transporter-seller separation.

Recommended Gas-Security Position

Prioritise indigenous gas restoration through producer liquidity, field development, low-BTU gas monetisation and stranded-gas commercialisation.
Operationalise TPA and allow direct E&P sales to creditworthy buyers through transparent network charges.
Preserve LNG as a flexible portfolio layer, subject to delivered-cost discipline, credit terms and terminal access.
Separate Sui transporter and seller roles so the network earns transport revenue rather than protecting commodity monopoly.
Apply value-based gas allocation so high-efficiency industrial, CHP and export-linked demand is prioritised over low-value, high-loss demand.
Do not treat IP as a standby molecule or Qatar negotiation proxy.
Keep IP as a deferred diplomatic option, reviewed only through delivered cost, financing, sanctions, winter-deliverability and offtake-bankability tests.

Executive Takeaway

Pakistan’s gas security should be built on domestic supply restoration, LNG flexibility and market reform, not on a new imported-pipeline obligation. Indigenous gas remains strategically superior because it supports reserve replacement, producer liquidity, royalties, field services, industrial reliability and lower import-fuel exposure. However, future domestic gas should not be treated as permanently cheap: as legacy fields decline, new and tight gas may require materially higher wellhead and delivered prices. The correct policy test is therefore not domestic gas versus IP in isolation, but a forward delivered-cost comparison between local gas, LNG and Iranian pipeline gas. LNG flexibility should be preserved because future market conditions may create more competitive and flexible procurement options. Iran–Pakistan should remain a deferred diplomatic option, considered only if price, sanctions, financing, winter deliverability and downstream offtake are contractually bankable.