Prior to the 2003 regime change no private sector gas projects had been implemented in Iraq and gas prices were heavily subsidized, both nationally and in a regional context**.

However, since 2007, two major gas projects have been signed, the first in Kurdistan by the Ministry of Natural Resources (MNR) and the second in Basra province by the Ministry of Oil (MoO). In addition the MoO has signed service contracts for three gas fields.

Each of these projects has been structured under different commercial terms, resulting in different gas price mechanisms.

However, the Iraqi government has contracted Booz & Company to develop the Iraq National Energy Strategy (INES), the executive summary of which was recently published in MEES (14 and 21 June). INES contains recommendations on gas pricing.

Furthermore, the World Bank is working on another pricing mechanism for associated gas in Iraq.

The details of these proposals to establish a unified federal framework for gas pricing are yet to be made available. Moreover, much will depend on the locality of these projects and the fiscal regime adopted.

The following is a brief outline of the shareholding of gas development projects in Iraq which will influence gas pricing policy for domestic consumption and exports:

1. Kurdistan region development of Khor Mor and Chemchemal gas fields***

•Service contract signed with the MNR (direct negotiation).

•Shareholders: 80% Dana Gas and Crescent Petroleum (JV), 10% MOL and 10% OMV.

•Current gas production 340mn cfd of feed gas for power generation.

•Current liquid production 15,000 b/d of condensate.

2. Basra Gas Company (BGC) gathering and development of associated gas**** from Rumaila, Zubair, West Qurna and possibly Majnoon fields.

•Service contract signed with the MoO (direct negotiation).

•Shareholders: 51% South Gas Company, 44% Shell and 5% Mitsubishi.

•Current gas production 350-400mn cfd (feed gas).

•Potential production of 2-4bn cfd.

3. Iranian gas supply to Iraq by pipeline^ for electricity generation.

•Agreement between the Iraqi Ministry of Electricity (MoE) and the Iranian MoO.

•Iran to supply Iraq with approximately 850mn cfd of dry gas.

•Gas sales agreement based on international market.

•A 56-inch pipeline from Iran to Iraqi midland provinces estimated to cost $365mn.

•Pipeline could be extended to Syria and Lebanon.

4. Non-associated gas fields, third licensing round. Service contracts signed with the MoO (see Table 1).

Tables included Table 1: Non-associated gas fields awarded in Iraq’s third licensing round

Field, Province Wining Consortium Remuneration ($/boe) Plateau Target Reserves (est)
Akkas, Anbar KOGAS (100%) 5.5 400mn cfd, 13yrs 2.1-5.6 tcf
Mansuriya, Diyala TPAO (50%), Kuwait Energy (30%), KOGAS (20%) 7.0 320mn cfd, 13yrs 3.3-4.5 tcf
Siba, Basra Kuwait Energy (60%), TPAO (40%) 7.5 100mn cfd, 9yrs 1.5-3.0 tcf
Source: MoO. A 35% Corporate Income Tax (CIT) applies to remuneration fees.


Since 2007, both the federal MoO and the KRG’s MNR have signed various long-term contracts through bid rounds and have entered into direct negotiations to form joint ventures (JVs) with IOCs. Table 2 outlines in chronological order the formation and structure of each JV.


Basra Gas Company

The economic model of the project was drawn up with the objective of maximizing benefits to Iraq while at the same time providing an acceptable return for the foreign partners. The gas pricing mechanism calculates the dry gas price based on a direct derivative of high sulfur fuel oil (HSFO), which is itself based on the crude oil price^^. The raw gas price is a backward calculation from the dry gas price utilizing a very large and detailed set of formulas.

The CIT rate is 35% and the Internal Rate of Return (IRR) of the project is set at around 15%. In the event the IRR exceeds this figure, the price of raw gas will be raised to increase SGC’s share in the revenue and reduce BGC’s IRR.

The formula for dry gas price calculation reads:

[Crude oil price/tonne converted to HSFO price/tonne]


[Reduction factor] / [Heating value of 1 tonne HSFO]

Hence, based on different crude oil prices of:

>$75, dry gas price is $3.22/mn BTU, and

>$100, dry gas price is $4.29/mn BTU, and

>$110, dry gas price is $4.72/mn BTU.

By comparison, elsewhere in the Middle East gas is currently sold at around $2.0-2.5/mn BTU at the current crude oil price of about $85/B.

As for the raw gas price for BGC, it is determined by a number of factors (such as IRR and windfall) introduced in a long series of equations^^^.

However, gas pricing elsewhere in Iraq may pose a serious challenge, since dry gas is priced as low as $0.60/mn BTU for the fertilizer industry and at not more than $1.20/mn BTU for electricity generation and other industries. Low domestic gas prices due to the heavy subsidy imposed by the government on BGC do not offer sufficient value to underpin the investment required.

Instead BGC must rely on the returns it can generate from the higher value of NGL (condensate and LPG) extracted from the raw gas and on a set of formulas, linked to the price of fuel oil that determines the net price SGC pays for gas processed by BGC.

Although BGC does not itself market any gas within Iraq, it obviously remains dependent on how quickly demand develops, particularly for gas fired power generation, petrochemicals, fertilizers and heavy industries where gas is the primary feedstock.

Iranian Gas Deal Scenario

The Iranian gas agreement with Iraq is rather ambiguous as a result of conflicting statements by senior Iranian officials and the scant information revealed by the Iraqi authorities.

The contract signed by the Iraqi MoE and the Iranian MoO is for 850mn cfd for 4 years^^^^. The price of the gas has not been announced, but is said to be at “world market prices,” whatever that means.

The Iranian Minister of Petroleum stated that the agreement with Iraq would provide the Iranian treasury with a daily minimum of $10mn. That would suggest an export gas price of around $11.76/mn BTU.

Furthermore, the 56-inch pipeline that is being constructed for that deal would appear not to be for the 850mn cfd deal alone.

Iran has plans to expand exports to Iraq in the future as well as exports through Iraq to Syria, Jordan and Lebanon, and an earlier statement from the Iranian Ministry of Petroleum claimed that 1,600mn cfd would eventually be transported through the pipeline.

Tables included Table 2: Iraq’s Joint Ventures with IOCs

Gas Field JV Operator Type of License Notes
Khor Mor (2.95 tcf proven reserves), Sulaimaniya, KRG Pearl Petroleum (Crescent Petroleum 40%, Dana Gas 40%, MOL 10%, OMV 10%) 20-year service contract awarded by the MNR, April 2007 Produces 350mn cfd and 15,000 b/d condensate
Chemchemal (2.19 tcf proven), Sulaimaniya, krg Pearl Petroleum (Crescent Petroleum 40%, Dana Gas 40%, MOL 10%, OMV 10%) 20-year HoA based service contract awarded by the MNR, April 2007 Awaits development. Expected 200mn cfd plateau
Akkas, Anbar KOGAS 100% 20-year service contract awarded by the MoO, LR3, 2010 Under d’ment. Expected 400mn cfd plateau
Mansuriya, Diyala TPAO (50%), Kuwait Energy (30%), KOGAS (20%) 20-year service contract awarded by the MoO, LR3, 2010 Under d’ment. Expected 320mn cfd plateau
Siba, Basra Kuwait Energy (60%), TPAO (40%) 20-year service contract awarded by the MoO, LR3, 2010 Under d’ment. Expected 1000mn cfd plateau
Flared Gas Capture: Basra, Rumaila, West Qurna-1 and Zubair. South Oil Company (51%), Shell (44%) Mitsubishi (5%) 25-year service contract awarded by the MoO through 2011 direct negotiation. Under d’ment. Expected 2-3bn cfd plateau for power gen. and F-LNG
Block-8 Gas Exploration Pakistan Petroleum (100%) 25-year service contract awarded by the MoO, LR4, 2012 Exploration under way
Source: Iraq Energy Institute (IEI) Analysis based on MoO (Gas Master Plan) and MNR public data.

Tables included table 3: netbacks for potential iraqi gas export routes

Gas Export Options Market Price Range ($/mn BTU) Transport Cost ($/mn BTU) Netback Price ($/mn BTU) Assumptions
To Kuwait (Pipeline) 10-15 ~0.2 ~10-15 >Market price equivalent to $80-120/B oil at a discount of 30% (similar to current LNG import prices). >Rehabilitation of the existing pipeline to Kuwait (0.4bn cfd).
To Syria (Pipeline) 4-5 ~0.6 ~3-4 >Market price aligned to the cost of developing own non-associated gas fields. >Development of a greenfield pipeline to Dair El-Zor (0.5bn cfd).
To Turkey (Pipeline) 7-11 ~0.6 ~6-10 >Market price aligned with average European imports. >Development of a greenfield pipeline to Antakiyah (1.4bn cfd).
To Jordan (Pipeline) 10-15 ~0.9 ~9-14 >Market price equivalent to $80-120/B oil at a discount of 30%. >Development of a greenfield pipeline to Risha (0.3bn cfd).
To Saudi Arabia (Pipeline) 5-12 ~0.4 ~5-12 >Market price aligned with the development cost of non-associated sour gas fields. >Development of a greenfield pipeline to Qurayyah (0.8bn cfd).
To Europe (via Nabucco Pipeline) 7-11 ~2.0 ~5-9 >Market price aligned with average European import prices (Germany, Italy, Spain and UK) taking 2008-11 period and for oil prices between $80 and $120/B. >Greenfield pipeline to Erzurum (0.8bn cfd) connecting to the Nabucco network onward to Vienna.
LNG To Asia 11-13 ~ 3.0 ~ 8-10 >Asian market price equivalent to Japan LNG import prices in 2008-11 and for oil prices between $80-120/B.
LNG To Europe 7-11 ~ 3.1 ~ 4-8 >European market price aligned with average European import prices (Germany, Italy, Spain and UK) over 2008-11 and for oil prices between $80-120/B. >Development of the BGC facility (0.6bn cfd).


Due to inherited practices and laws, Iraq’s gas market requires serious policy reforms before a viable price mechanism can be defined.

The federal government needs to work out a plan to phase out subsidies and make the local gas market competitive, while improving the country’s ability to attract foreign investors for international trades. Table 3 shows the netbacks of exports to selected regional and international markets^^^^^.

As for the IEA’s Iraq Energy Outlook, this assumes that dry gas costs are low, since production in Iraq is generally accompanied by substantial output of natural gas liquids, while supply costs for individual projects could vary significantly.

The gas feedstock is assumed to be non-associated, with the exception of southern production feeding into a possible LNG plant, which is assumed to be associated gas.

In this IEA scenario, production costs do not include taxes or royalties, and the cost of shipping LNG to the Asia Pacific market is an average of the cost of transportation to the Indian and Chinese markets. The bulk of the cost, in any case, consists of the cost of facilities for LNG liquefaction, and import price assumptions for 2020 are from the IEA central scenario.


In Iraq the current price of domestic gas is too low to attract investment. Besides the perennial problem of local subsidies, which need to be phased out, the absence of a federal regulator to manage gas continues to hamper the Iraqi government’s efforts to persuade producers to supply the domestic market, while the export market is more lucrative for international oil companies (IOCs). Moreover, the price of gas in many of Iraq’s neighbors is probably too low to allow Iraqi exports to them.

Through inattention and a lack of understanding the MoO and MNR have failed to encourage the proper development of the gas sector in order to secure the maximum netback from gas production, and they are currently focused on short-term gains alone, which may cause long-term damage.

What is needed at this point, therefore, is a third party consultative body with no interest in gas investment to assist government bodies at the federal and regional level until a constitutionally formed regulatory body such as the Federal Oil and Gas Council (FOGC) is up and running.

Until such a body is in place, Iraq gas producers might consider setting up a coordinating body at a national level to agree a common position on gas pricing. Otherwise, once one party agrees on a price, it is likely to set a precedent for all the rest. A low price would be a disservice to Iraq and a disincentive for the industry to develop its resources properly.

*Luay al-Khatteeb is Founder and Executive Director of the Iraq Energy Institute.

**Iraq dry gas is a subsidized and priced at $1.2/mn BTU. In Saudi Arabia gas is priced at $0.75 and in Iran at $2.2/mn BTU. These prices are very low compared to tradable gas in international markets.

***Signed in April 2007.

****Signed in July 2011.

^Pipeline agreement signed in July 2011 and gas sales agreement in July 2013.

^^IEI Insight on Basrah Gas Company contract.

^^^IEI analysis of BGC contract.

^^^^Iraq Oil Report, 23 July 2013.

^^^^^Iraq National Energy Strategy, 2013, Booz & Company analysis and recommendations to the government of Iraq.