IRAN’S AGGRESSIVE NATURAL GAS EXPANSION PLANS
By Hedayat Omidvar
Energy Tribune, TX
Posted on Sep. 17, 2007
As global energy demand rises, natural gas increasingly plays a
strategic role. The sector is poised for tremendous growth over the
next two decades and some believe that it may overtake oil as the
prime fuel between 2020 and 2030. Iran’s huge proven reserves –
some 28 trillion cubic meters (about 995 trillion cubic feet) -
should make it a key player in the emerging global gas business.
These impressive reserves figures – second only to the Russian
Federation’s – underscore Iran’s enormous potential. The National
Iranian Gas Company (NIGC) plans the steady expansion of transmission
and processing infrastructure in a program aimed at increasing imports
and exports of natural gas, which will take natural gas to parts
of the Islamic Republic not yet reached by distribution systems and
boost exports by pipeline and in the form of LNG.
More than 60 percent of Iran’s gas reserves are located in
non-associated undeveloped or partially developed fields. The major
non-associated gas fields include South Pars (280-500 tcf of gas
reserves), North Pars (50 tcf), Kangan (29 tcf), Nar (13 tcf), and
Khangiran (11 tcf). There are also several other large gas fields
with multi-tcf reserves. However, most of the gas will come from the
offshore South Pars gas field, which is being developed in stages.
Supplementing that supply will be imports from Turkmenistan and,
soon, from Azerbaijan.
South Pars was first identified in 1988 and was originally thought to
contain just 128 tcf. Current estimates show it to contain at least
280 tcf (with some estimates going as high as 500 tcf) as well as
over 17 billion barrels of condensate.
By 2010, more than 500,000 barrels per day of condensates could be
produced at South Pars, mainly for domestic consumption. Designed
in 28 phases, so far only 18 phases have been activated. By 2015,
condensate production from South Pars phases 1-14 is expected to reach
628,000 bpd. Besides condensate production and enhanced oil recovery,
South Pars natural gas is intended for both domestic consumption and
exports. South Pars can produce more than 400 million cubic meters
per day (14.2 billion cubic feet/day). Considering internal demand,
half of this production can be assigned to exports.
Internal consumption represents a rapidly growing demand on Iranian
gas supply. The NIGC expects internal consumption to rise to 156.2
bcm per year in 2009 (13.2 bcf/day). (Editor’s Note: The National
Iranian Oil Company is purported to raise oil production to about
5.4 million barrels per day by 2009.)
Market Expansion
By 2009, NIGC expects to have 29,400 kilometers of gas transmission
pipeline in place and a distribution network of 125,000 km. Domestic
gas consumption that year will represent 69 percent of the Iranian
energy market, and 54 million Iranians will have access to natural
gas – about 80 percent of the population.
NIGC plans to invest about $18 billion through 2009 in high-pressure
gas pipelines, compressor stations, gas-processing plants, underground
storage, distribution networks, and maintenance.
Pipeline Projects
Many of the pipeline projects planned by NIGC will be attached to the
Iranian Gas Transmission (IGAT) system. Transmission pipelines with
a length of 20,000 km take gas from various sources to destinations
across the whole country. Lines with diameters of 56, 48, and 42 inches
have been employed to carry more than 500 million cubic meters per day
(17.7 bcf/day) of natural gas.
The IGAT IV pipeline will carry 110 (mcm/day) of gas from South
Pars and the Parsian gas plants to consumption areas. The project
includes 1,030 km of 56-inch pipe in two sections and two compressor
stations. Parts of IGAT IV have begun service. The main part of the
pipeline was connected with the Pol Kaleh compressor station in Isfahan
in 2004; a 351-km section to Fars Province became operational in 2004.
A second stage of IGAT IV will include a 42-inch spur line to Kerman,
a 24-inch line to serve a Fars petrochemical plant, a second 40-inch
line to Yazd, and a 40-inch Isfahan-Mobarakeh pipeline.
The 56-inch IGAT V trunkline will carry 75 mcm/day of sour gas from
South Pars Phases 6-8 to Khoozestan oil fields for injection. It will
connect Assaluye and Agha Jari, a distance of 504 km, and will have
five compressor stations.
The IGAT VI pipeline will generally parallel IGAT V to serve gas
needs of Bushehr and Khoozestan provinces, including oil field
injection. With a length of 492 km and a diameter of 56 inches, it will
have a capacity of 90 mcm/day. Two compressor stations are planned.
IGAT VII, 860 km of 42 to 56-inch line, will carry gas produced in
South Pars Phases 9 and 10 for use in Sistan and Baluchestan provinces
in southern Iran, and possibly for export to the U.A.E., Pakistan,
and India.
IGAT VIII, a 1,050-km, 56-inch line, will carry South Pars gas to
the Parsian gas plant and north to a line serving Tehran. It will
have 10 compressor stations with a total of 1.8 million hp.
To meet growth in gas demand in the northern and eastern provinces
of Semnan, Khorasan, Golestan, and Mazandaran, NIGC plans a second
pipeline between Parchin and Sangbast, 790 km long with a diameter of
48 inches, and a 110-km, 40-inch segment between Miami and Jajarm. The
system will have four compressor stations and will handle South Pars
gas delivered through IGAT VIII.
To serve the western and northern provinces of Hamadan, Kordestan,
Zanjan, as well as East and West Azerbaijan, NIGC plans to lay 280
km of 48-inch pipeline between a compressor station at Saveh and
the city of Bijar, and 192 km of 40-inch pipeline between Bijar and
Miandoab. Other segments with diameters of at least 30 inches will
boost pipeline lengths planned for this region to 950 km.
Gas Processing Projects
Seven gas processing plants have recently been completed or are planned
and under construction in Iran. The Parsian plant began treatment
operations in 2003, dehydrating 20 mcm/day of gas from Tabnak field
and stabilizing 12,000 bpd of condensates.
Construction of the new processing facilities will proceed in two
phases, one with an inlet capacity of 48 mcm/day and the other, 28
mcm/day. The complex is designed for annual yields of 85,000 tons of
ethane, 11 million barrels of pentanes-plus, 310,000 tons of butane,
and 450,000 tons of propane.
The Bidboland II plant will sweeten and process 57 mcm/day of gas at
facilities that will be built about 14 km southeast of the existing
Bidboland plant. Fed by gas from the Pazanan, Gachsaran, and Bibi
Hakimeh fields, the new plant has design output capacities of 15
bcm of sweet gas, 1.48 million tons of ethane, 1.51 million tons of
propane and butane, and 860,000 tons of natural gasoline.
About 6 bcm per year from the plant are targeted for oil-field
injection, the rest for delivery into the gas grid. Ethane will go to
a petrochemical plant at Arvand. The other products will be exported
through Bandar Mahshahr.
In a separate project, NIGC plans a gas processing plant 25 km
northwest of the city of Ilam and 12 km west of Chavar in western
Iran. The Ilam plant will process gas from Tange Bijar and Kamankooh
fields.
Built in two phases, it will have an inlet capacity of 10 mcm/day and
will supply dry gas to cities in Ilam Province and the transmission
network and liquids to a petrochemical plant at Ilam.
NIGC also plans a small processing plant at Masjed Soleiman with
inlet capacity of 1 mcm/day and is studying a plant able to process
14 mcm/day at South Gesho sour gas field in Hormuzgan Province. The
South Gesho facility, near an existing plant at Sarkhon, would have
two trains with identical inlet capacities.
After removal of 600 tons/day of sulfur and 9,000 bpd of condensate,
sweet gas would move to markets in the southeastern part of the
country, including some to a power plant at Bandar Abbas.
Storage Projects
To overcome seasonal fluctuations in consumption, installation of
underground gas storage has been recognized as the best choice. Three
underground storages are under study, with some degree of progress,
to ensure natural gas supply to internal users and export destinations.
NIGC has also identified several reservoirs that might be converted
for underground gas storage. One of them is Sarajeh gas and condensate
field, about 40 km east of Qom, whose production rates have been
restricted by surface equipment for about 45 years. NIGC believes
that by working over old wells and drilling new ones it can deplete
the reservoir in two years and convert it to storage. Another prospect
for gas storage is the Yortsha Dome saltwater reservoir 25 km south of
Varamin. NIGC has acquired 2D and 3D seismic data over the reservoir
and plans to drill vertical and horizontal wells to prepare it for
storage. Another saltwater reservoir under study for use as gas
storage is the Talkheh Dome in central Iran, which also contains
negligible amounts of light and heavy hydrocarbons. A single well
drilled in 1960 found the structure. NIGC has 2D seismic data from
the area and plans a 3D survey.
Other areas that NIGC thinks might have reservoirs amenable to gas
storage are in the provinces of Abardejno, Siahkooh, Marehtapeh,
Prandak, and East Azerbaijan.
Expansion of Iran’s gas industry follows a strategy in place since
the early 1990s to displace oil with gas in domestic consumption. In
2002, gas moved ahead of oil in Iran’s total energy consumption. Gas
now claims 70 percent and oil, 30 percent of Iran’s overall primary
energy use.
Export Markets
The strategic role of the Persian Gulf and the huge amount of gas
reserves in this area have provided a good opportunity for Iran to
export gas to consuming countries through pipeline or in the form of
LNG. NIGC believes pipeline exports can reach 44 bcm/year in 2009 and
110 bcm/year by 2020. Besides Turkey, potential customers for Iranian
gas include Ukraine, Europe, India, Pakistan, Armenia, Azerbaijan,
Georgia, and China. NIGC is targeting LNG exports from three planned
liquefaction projects to China, Thailand, and India of 35 mcm/day in
2009 and 180 mcm/day in 2020.
Assalouyeh and Kish Island have been named as possible LNG export
terminals.
Oman and Iran have signed an agreement to develop offshore gas fields
in Iran and take the gas to Oman.
The gas from the joint Bukha-Hengam and other fields would be converted
into LNG at Oman’s Qalhat LNG plant and marketed as exports by a joint
company. The agreement also calls for joint petrochemical projects.
Bahrain has started discussions with Iran over importing natural gas
through a new pipeline by 2015.
As part of its plans to meet the Kingdom’s future electric power
needs, Bahrain has implemented a twin-pronged strategy to boost gas
supply. This involves both increasing domestic output and negotiating
import agreements with its gas-rich neighbors.
The project for transferring gas to Europe is also economically
attractive and will benefit all parties involved. Turkey and Ukraine
have been considered as alternative routes, but the former is less
expensive.
By the end of 2007, Iran expects to be exporting about 300 bcf/year
of gas to Europe via Turkey.
Since the discovery of natural gas reserves in Iran’s South Pars
fields, the Iranian government has increased efforts to promote
higher gas exports abroad. The prospects for profit are especially
good in south Asian countries like India and Pakistan, where natural
gas reserves are low and energy demand exceeds supply. Pakistan and
Iran signed a preliminary agreement for the construction of a natural
gas pipeline linking the Iranian South Pars natural gas field in the
Persian Gulf with Karachi, Pakistan’s main industrial port. Iran
later proposed an extension of the pipeline from Pakistan into
India. Although India and Iran signed a memorandum of understanding
in 1993 for a land-based natural gas pipeline, regional political and
security concerns continue to block the completion of a feasibility
study.
Import Markets
Apart from natural gas exports, Iran has also discussed
importing natural gas from Azerbaijan and already imports it from
Turkmenistan. This is basically for use in Iran’s northern areas,
far from the country’s main natural gas reserves in the south.
In December 1997, Turkmenistan launched the $190 million
Korpedze-Kordkoy pipeline to Iran, the first natural gas export
pipeline in central Asia to bypass Russia. According to the 25-year
contract’s terms, Iran will take between 5 and 6 bcm of natural gas
from Turkmenistan annually, with 35 percent of Turkmen supplies
allocated as payment for Iran’s contribution to building the
pipeline. Iran’s gas imports from Turkmenistan will peak at 8 bcm
per year.
Armenia and Iran have agreed to a long-term deal under which Iran
will supply an annual 1.3 tcf of natural gas to Armenia over 20
years (starting in 2007) in exchange for electricity supplies from
Armenia. The two countries will also build an 85-mile gas pipeline
at a cost of more than $200 million (construction on the pipeline
began in late November 2004). Armenia is also reportedly keen to
receive credit from Iran for building hydroelectric plants on the
Aras River in exchange for electricity supplies to Iran. These deals
are expected to boost regional trade and cooperation between Iran
and central Asian states.
Iran’s gas industry now contributes the lion’s share to the
country’s fossil fuel basket and it has entered an intense stage of
development. For more than 40 years, gas has played a secondary role
to oil. But the growing demand for natural gas in the residential and
industrial sectors, along with surging export demand, have launched a
new era. To respond adequately, Iran’s gas sector needs investments,
especially in upstream development, technology transfer, and export
and import facilitation. With or without foreign investment, Iran
will be a key gas exporter for decades to come.
Since 1992, Hedayat Omidvar has been a gas consumption expert in
the National Iranian Gas Company’s corporate planning department. He
currently heads NIGC’s strategic studies, research, and technology
department, and serves on the marketing committee of the International
Gas Union.
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