The 1973 Iraq-Turkey crude oil pipeline agreement, last renewed in 2010, terminates on July 27. Turkey gave formal notice of termination in July 2025 and has kept a draft replacement on the table since. Iraq’s cabinet has now authorized the Oil Ministry to open negotiations on a long-term arrangement, with the stated files limited to transit tariffs, delivery volumes, and technical and commercial terms.

The treaty lapses during the sharpest contraction in Gulf energy shipping in recent memory, and that has turned a technical renewal into a contest over the shape of Iraq’s export map.

Context: The Hormuz numbers are stark. Before the US-Israeli strikes on Iran on February 28, roughly 70 energy and product vessels crossed the strait each day. Daily transits have run below seven since March and below six in May. Iraq moved about 10 million barrels through Hormuz in April, against roughly 93 million barrels a month before the war. Basra loading, which carried almost all Iraqi exports for a decade, now reads as a single point of failure.

That is why the northern route matters again. Exports through Ceyhan restarted in March under a Baghdad-Erbil arrangement, initially near 170,000 bpd, with revenue directed to the federal treasury. Iraq now moves roughly 200,000 bpd through Ceyhan and plans to lift that toward 500,000.

The legal background shapes every Iraqi position in the talks. The pipeline went dark in 2023 after Iraq won arbitration against Turkey over unauthorized Kurdish exports between 2014 and 2018, with Turkey ordered to pay about $1.5 billion. Baghdad will not sign a successor agreement that leaves ownership of the crude, the marketing channel, or the payment route open to a parallel Erbil-Ankara reading.

Ankara, for its part, is not negotiating a simple renewal. Turkish Energy Minister Alparslan Bayraktar has argued repeatedly that the line carries a nominal capacity near 1.5 million bpd and has never been used at scale. Any new agreement, he says, must include a mechanism to guarantee fuller use. Reaching that volume requires extending the line south toward Basra, since northern production cannot fill it.

Turkey folds this into the wider Development Road from Faw to Turkey, reframed as an energy corridor carrying oil, gas, petrochemicals, refining, and electricity alongside road and rail. The draft Turkey submitted reaches well beyond crude transit to cover field development, refining, power generation and transmission, and the BOTAŞ terminal at Ceyhan. Running in parallel, Turkey’s state company TPAO has been building upstream partnerships with BP, ExxonMobil, and Chevron, with Bayraktar naming Iraqi and Kirkuk fields as the priority.

Analysis: The arithmetic behind Turkey’s demand is not in dispute. Basim Mohammed Khudair, formerly deputy oil minister and now oil minister, puts Kirkuk production near 380,000 bpd, most of it claimed by domestic refineries, leaving roughly 250,000 available for export. Even with the Kurdistan Region contributing, the northern axis reaches around 650,000 bpd, far short of the 1.5 million Turkey wants to monetize.

Kirkuk cannot fill Ceyhan. Only Basra can. That single fact is why the negotiation has migrated from a Kirkuk-Ceyhan renewal to a Basra-Haditha-Ceyhan redesign.

Baghdad’s instrument is the Basra-Haditha pipeline, which the Oil Ministry calls the backbone of the northern export system. In April, Sudani ordered a dedicated body to implement it, chaired by the ministry undersecretary, building on contracts signed in August 2024 and January 2025. Funding of $1.5 billion is committed this year under the Iraqi-Chinese framework against an estimated $5 billion total. The line would connect to the existing Turkey route through a 200-kilometre, 42-inch Haditha-IT1A link while also feeding domestic refineries.

Baghdad has chosen a turnkey, state-financed model with full Oil Ministry ownership, after rejecting an investment structure that would have handed an outside party long-term transit rights. If Turkey is seeking ownership leverage under the heading of investment, that is the Iraqi red line.

The decisive feature of the Iraqi design is that Basra-Haditha is multidirectional. From Haditha, crude could move north to Ceyhan. In theory, it could also support future western exits toward Baniyas and Tartus on the Syrian coast, or southwest toward Aqaba in Jordan. These branches should not be read as equally imminent projects. Their immediate value is strategic optionality. They give Baghdad a map of alternatives, even before all of them become physical export routes.

That is the part of Iraqi strategy the Turkish framing obscures. Baghdad is not trying to replace Hormuz with Ceyhan. It is trying to build a hub from which no single outlet becomes decisive. A Mediterranean exit through Syria and a Red Sea exit through Jordan would be hedges against the very dependence Turkey is trying to create. Diversification away from Hormuz is worth little if it simply concentrates the same risk on Turkish territory, and Baghdad knows it. The point of the western options is not that they will all be built at once. It is that each one weakens any single transit state’s hold over Iraqi crude.

This is where the two governments overlap without aligning. Both want Ceyhan flowing at higher volumes, and a deal is plausible. But Turkey wants to expand Ceyhan and tie Iraqi southern oil to Turkish soil, while Iraq wants to federalize Ceyhan and keep other exits alive. Each is bargaining from the same pipeline for a different kind of leverage.

For the Kurdistan Region, the trajectory is unfavourable. Its 2014-built line, with a design capacity near 900,000 bpd, remains physically useful in the short term while the ministry-controlled Kirkuk-Fishkhabur line, rated near 1.5 million bpd, is rehabilitated as a federal bypass. Once that bypass and Basra-Haditha are in place, the KRG pipeline becomes a feeder rather than a strategic bottleneck.

Baghdad’s aim is not necessarily to shut it. The aim is to strip it of independent commercial authority. Turkey signs with Baghdad alone, SOMO markets the crude, and revenue runs through the federal treasury. The KRG line may remain part of the infrastructure, but not as the basis for a parallel political economy.

The negotiation need not resolve as a binary between a grand bargain and collapse. The two sides could still extend the existing framework, and Turkey’s main lever there is the tariff itself. The mechanism to guarantee full use that Bayraktar keeps invoking points to a volume-linked fee: a higher per-barrel charge, or a take-or-pay floor, when throughput stays low, and a lower charge once Iraq commits to filling the line. The pricing is designed to make underuse expensive for Baghdad and to pull it toward connecting Basra. In Turkey’s design, the fee question and the Basra question are one question.

The realistic outcomes therefore sit on a spectrum. At one end is a short technical extension that keeps crude moving past July 27 while the larger questions stay open. In the middle is a volume-tiered renewal that prices Iraqi commitment into the tariff. At the other end is the full energy-corridor package Turkey has drafted, bundling transit with field development, refining, power, and the Ceyhan terminal.

Iraq’s interest is to keep the transit renewal narrow and resist folding the investment and infrastructure package into the same instrument, even while accepting Turkish firms in discrete field, downstream, or pipeline contracts. A phased path, narrow transit now and a wider arrangement later, suits Baghdad more than Ankara.

Whatever the structure, a deal struck before the deadline will not restore the pre-2023 model. The likeliest endpoint is Ceyhan returning as a federal corridor under SOMO and the treasury, the KRG line tolerated as infrastructure without political-commercial autonomy, and Turkey gaining volume guarantees and investment access but not a chokehold over Iraqi oil.

Baghdad’s wager is that holding the Syrian and Jordanian options open is what keeps Ceyhan a corridor rather than a second Hormuz.