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South Pars / North Dome Gas-Condensate field
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The South Pars / North Dome field is a gas condensate field located in the Persian Gulf. It is the world's largest gas field, shared between Iran and Qatar.
This gas field covers an area of 9700 square kilometers, of which 3700 square kilometers (South Pars) is in Iranian territorial waters and 6000 square kilometers (North Dome) is in Qatari territorial waters.
field consists of two independent gas-bearing formations, Kangan (Triassic) and Upper Dalan (Permian).
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Encyclopedia
The South Pars / North Dome field is a gas condensate field located in the Persian Gulf. It is the world's largest gas field, shared between Iran and Qatar.
This gas field covers an area of 9700 square kilometers, of which 3700 square kilometers (South Pars) is in Iranian territorial waters and 6000 square kilometers (North Dome) is in Qatari territorial waters.
Field geology
The field consists of two independent gas-bearing formations, Kangan (Triassic) and Upper Dalan (Permian). Each formation is divided into two different reservoir layers, separated by impermeable barriers. The field consists of four independent reservoir layers K1, K2, K3, and K4.
The field is a part of the N-trending Qatar Arch structural feature that is bounded by Zagros fold belt to the north and northeast.
In the field, gas accumulation is mostly limited to the Permian–Triassic stratigraphic units. These units known as the “Kangan–Dalan Formations” constitute very extensive natural gas reservoirs in the field and Persian Gulf area, which composed of carbonate–evaporite series also known as the Khuff Formation.
Permian–Early Triassic has been divided into Faraghan (Early Permian), Dalan (Late Permian) and Kangan (Early Triassic) Formations.
Reserves
According to International Energy Agency, the combined structure is the world’s largest gas field.
In-place volumes are estimated to be around 1800 tcf (51 tcm) gas in place and some 50 billion barrels of condensate in place. With in place volumes equivalent to 360 billion barrels of oil (310 Billion Boe of Gas and 50 Billion bbl of condensate) the field is the world’s biggest conventional hydrocarbon accumulation even bigger than Ghawar oil field, which has 170 billion barrels of original oil in place.
The field recoverable gas reserve is equivalent to some 215 billion barrel of oil and it also holds about 16 billion barrels of recoverable condensate corresponding of about 230 billion barrel of oil equivalent recoverable hydrocarbons.
The gas recovery factor of the field is about 70%, corresponding of about of total recoverable gas reserves which stands for about 19% of world recoverable gas reserves.
The estimates for the Iranian section are 500 tcf (14.2 tcm) of gas in place and around 360 tcf (10.1 tcm) of recoverable gas which stands for 36% of Iran's total proven gas reserves and 5.6% of the worlds proven gas reserves.
The estimates for the Qatari section are 900 tcf (25.5 tcm) of recoverable gas which stands for almost 99% of Qatar's total proven gas reserves and 14% of the worlds proven gas reserves.
Table 1-"South Pars / North Field Gas Reserves"
| | In Place Gas Reserve (Tcf) | Recoverable Gas Reserve (Tcf) |
|---|
| South Pars | 500 | 360 | | North Dome | 1300 | 900 | | Total Field | 1800 | 1260 |
However it shall be noted that due to the fact that field is a common field and the reservoir is highly homogenous, then ultimate recoverable reserves of each country may vary from this technical assessment which only considers the static data and doesn’t include rate of gas migration. So it is better to say ultimate recoverable reserves of each country would be a factor of cumulative gas production by each of them.
Iranian section also holds 18 billion barrels of condensate in place of which some 9 billion barrels are believed to be recoverable, while Qatari section believed to contains some 30 billion barrels of condensate in place and at least some 10 billion barrels of recoverable condensate.
The field is rich in liquids and yields approximately 40 bbl of condensate per 1 MMcf of gas. It has also very high level of well productivity which in average stands for 100 MMcf per day per well.
Reserve Uncertainties
In 2005,Qatar Petroleum became worried the North Dome’s reserves were being developed too quickly, which could reduce reservoir pressure and possibly damage its long-term production potential. In early 2005, the government placed a moratorium on additional development projects at the North Dome pending a study of the field’s reservoirs. This assessment is not expected to end until after 2009, meaning new projects are unlikely to be signed before 2010. However, this did not affect projects approved or underway before the moratorium.
On 29 October 2007, Qatargas CEO Faisal Al Suwaidi stated that the 5 year moratorium on new North Field gas development projects, imposed in 2005, could be extended to 2011 or 2012.
The 2005 moratorium by Qatar and the subsequent extension of that raised some questions about the actual proven reserves in Qatari side of the field. There are some news that ConocoPhillips drilled an unexpected dry hole in the North Field and this event was at least a partial catalyst for a revamped perspective on the North field structure and potential.
Another supporting evidence for skepticism about the real scale of Qatari’s reserves comes from the latest ongoing exploration round in Qatar which is targeting exploration of gas in pre-Khuff formation. Even one of the blocks is exactly located beneath the North Dome Field.
Some petroleum industry experts believe that 900 Tcf of gas reserves reported by Qatar stands for gas in place volume and consequently Qatar's recoverable gas reserves should be about 550 to 600 Tcf. The moratorium applied by Qatar Petroleum for future development of the field is a supporting evidence of this belief. They believe, if as Qatar claims the North Dome holds 900 Tcf recoverable gas, the reservoir should be capable of producing much more than current planned capacity (see Table 2). The results of current ongoing study undertaken by Qatar on the field will determine the actual reserves of the Qatari section.
South Pars Development
The South Pars Field was discovered in 1990 by NIOC. The Pars Oil and Gas Company. a subsidiary of NIOC, has jurisdiction over all South Pars-related projects. Field development has been delayed by various problems - technical (i.e., high levels of mercaptans and foul-smelling sulfur compounds), contractual issues and recently politics.
Gas production started from the field by commissioning phase 2 in December 2002 to produce 1bscf/d of wet gas. Gas is sent to shore via pipeline, and processed at Assaluyeh.
Condensate production from South Pars is currently , and by 2010, could increase to over .
NIOC is planning to develop the field in 24 to 30 phases, capable of producing about 25 to 30 bcf of gas per day.
Each standard phase is defined for daily production of 1 bcf of gas, 40,000 bbl of condensate, 1500 tonnes of LPG and 200 tonnes of Sulfur, however some phases have some different production plans.
By the beginning of 2008 phases 1,2,3,4 and 5 has been brought to production and by the end of 2008 phases 6,7,8,9 and 10 will be on stream. Phases 12,15,16,17,18,19,27 and 28 are under different development stages.
Phases 11,13 and 14 are dedicated to Pars LNG. and Persian LNG projects.
Phase 11 is dedicated to the Pars LNG project which is a partnership between NIOC (50%), Total (30%) and Petronas (20%). The project is designed for an initial capacity of two trains of 5 million tons of LNG per year each.
Phase 12 is dedicated to the Iran LNG project which is wholly owned by NIOC. The project is designed for an initial capacity of two trains of 5 million tons of LNG per year each.
Phase 13 and 14 are dedicated to the Persian LNG project which is a partnership between NIOC (50%), Royal Dutch Shell (25%) and Repsol YPF (25%). The project is designed for an initial capacity of two trains of 8 million tons of LNG per year each. In May 2008, parties agreed to exchange block 13 with block 20 or 21 due to NIOC interests in acceleration of the development phase 13.
On March 2009, development of phase 27&28 was awarded to Petropars and development of phase 21&22 was awarded to OIEC based on an EPC scheme.
Development of phases 19 and 22 to 26 are under negotiation.
Based on the latest plan, Phase 19 will be developed as a single phase for producing of 1500 MMcf/d of gas.
Development of phases 22, 23 and 24 may be assigned to Turkey.
South Pars Phases
- Phase 1 was developed by Petropars to produce 1 billion cubic feet (28,000,000 m3) per day of natural gas, 40,000 barrels per day of condensate, 1500 Tons of of LPG per day plus 200 Tons of Sulfur per day.
- Phases 2 and 3 were developed by a consortium of Total, Petronas and Gazprom to produce 2 billion cubic feet (57,000,000 m3) per day of natural gas, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day. It came online in March 2003.
- Phases 4 and 5 were developed by Eni and Petropars, to produce 2 billion cubic feet (57,000,000 m3) per day of rich natural gas, 75 MMcf/d of Ethane, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day.
- Phases 6 to 8 being developed by Petropars and Statoil to produce lean gas for re-injection into the Aghajari oilfield, and heavy gas and condensate for export. It involves construction of three offshore platforms in addition to the land based facilities. Statoil is developing the offshore platforms while Petropars is developing the land based facilities. A 31-inch (790 mm) pipe will be laid from each platform to the coast. These phases will produce 3 billion cubic feet (84,000,000 m3) per day of natural gas, 70 MMcf/d of Ethane, 120,000 barrels per day of condensate, 4500 Tons of of LPG per day plus 600 Tons of Sulfur per day.
- Phases 9 and 10 being developed by LG of Korea. These phases will produce 2 billion cubic feet (57,000,000 m3) per day of natural gas, 75 MMcf/d of Ethane, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day.
- Phases 11 will produce LNG, the development contract currently being bidded by TotalFinaElf .
- Phases 12 development begin carried out by Petropars. This phase will produce 2.5 billion cubic feet (70,000,000 m3) per day of rich natural gas, 75 MMcf/d of Ethane, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day.
- Phase 13 and 14 development will be for LNG production and is being bidded by Shell .
- Phases 15 and 16 development was awarded to "Gharargah Khatam-ol Anbia". These phases will produce 2 billion cubic feet (57,000,000 m3) per day of natural gas, 75 MMcf/d of Ethane, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day.
- Phases 17 and 18 development was assigned to a consortium of Oil Industrial Engineering and Construction Company (OIEC), Iran Offshore Engineering and Construction (IOEC) and Petropars. These phases will produce 2 billion cubic feet (57,000,000 m3) per day of natural gas, 75 MMcf/d of Ethane, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day.
- Phase 19 development was awarded to OIEC. These phases will produce 2 billion cubic feet (57,000,000 m3) per day of natural gas, 75 MMcf/d of Ethane, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day. As it is understood this phase is defined within phase 1 so it can be regarded as some kind of expansion for phase 1.
- Phases 20 and 21 development was awarded to OIEC. These phases will produce 2 billion cubic feet (57,000,000 m3) per day of natural gas, 75 MMcf/d of Ethane, 80,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day.
- Phases 22, 23 and 24 are in tender and are located in the north-eastern frontier of the field.
- Phases 25 and 26 are in tender.
- Phases 27 and 28 development was assigned to Petropars.These phases will produce 2 billion cubic feet (57,000,000 m3) per day of natural gas, 75 MMcf/d of Ethane, 75,000 barrels per day of condensate, 3000 Tons of of LPG per day plus 400 Tons of Sulfur per day.
Table 2-South Pars Gas and Condensate Production Plan
| Phase | General Contractor | 2003 | 2004 | 2005 | 2006 | 2007 | 2008 | 2009 | 2010 | 2011 | 2012 | 2013 | 2014 | 2015 | 2016 |
|---|
| 1 | Petropars | | 500 | 750 | 750 | 750 | 750 | 750 | 750 | 750 | 750 | 750 | 750 | 750 | 750 | | 2&3 | Total | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | | 4&5 | Eni | | | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | | 6,7&8 | Petropars/Statoil | | | | | | 1000 | 2500 | 3700 | 3700 | 3700 | 3700 | 3700 | 3700 | 3700 | | 9&10 | ?Consortium of LG Korea,OIEC and IOEC | | | | | | 1000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | 2000 | | 11 | Total | | | | | | | | | | | | 1000 | 2000 | 2000 | | 12 | Petropars | | | | | | | | | 1000 | 2000 | 3000 | 3000 | 3000 | 3000 | | 13 | Shell/Repsol | | | | | | | | | | | | 1000 | 2000 | 2000 | | 14 | Shell/Repsol | | | | | | | | | | | | 500 | 1000 | 1000 | | 15&16 | "Gharargah Khatam-ol Anbia" | | | | | | | | | | | | 1000 | 2000 | 2000 | | 17&18 | Consortium of IDRO,IOEC and OIEC | | | | | | | | | | | | 1000 | 2000 | 2000 | | 19 | TBD | | | | | | | | | | | | | 500 | 1500 | | 20&21 | OIEC | | | | | | | | | | | | | 1000 | 2000 | | 22,23&24 | TBD | | | | | | | | | | | | | 1000 | 3000 | | 25&26 | TBD | | | | | | | | | | | | | 1000 | 2000 | | 27&28 | Petropars | | | | | | | | | | | | | 1000 | 2000 | | Total Gas Production MMcf/d | | 2,000 | 2,500 | 4,750 | 4,750 | 4,750 | 9,250 | 10,450 | 10,450 | 11,450 | 12,450 | 13,450 | 17,950 | 24,950 | 29,450 | | Total Condensate Production kbbl/d | | 80 | 100 | 190 | 190 | 190 | 370 | 420 | 420 | 460 | 500 | 540 | 720 | 1,000 | 1,200 |
Table Sources: NIOC, Pars Oil & Gas Company, Shana and Media
Development Delays and Criticisms
While several phases of South Pars gas field are still waiting for development and the ongoing development phases are facing delays, NIOC authorities are conducting negotiations for development of other Iranian offshore gas fields like North Pars, Kish, Golshan, Ferdows and Lavan.
Many Iranian energy analysts believe that NICO authorities should focus on full development of South Pars field prior to conduction of any new project for development of other undeveloped Iranian offshore gas fields.
The priority of South Pars full development is not only due to its shared nature with Qatar, but also with huge capability of the field to add significant liquid production to Iranian liquid export capacity.
On the 27th of February 2009 one of the members of Iranian Parliaments, criticized lack of attention on the importance of acceleration of South Pars field development and the field development delays.
Scale and Impacts of Delays
By the end of 2008 Qatar’s cumulative production from the field was two times higher than Iran’s cumulative production from the field. Qatar produced about 20 Tcf of gas in the period of 1997 to 2008, while Iran produced about 10 Tcf of gas in the period of 2003 to 2008.
Double level of Qatar’s cumulative gas production from the field is forecasted to continue at least for short term, for example; by the end of 2011, Qatar’s total cumulative production from the field will reach to 41 Tcf of gas, while Iran’s cumulative production from the field will reach to 21 Tcf of gas in the same year.
In terms of annual production also Qatar’s production is almost double the Iranian production level.
In 2009 Qatar’s annual production will reach to 6.4 Tcf per year while in the same year Iran’s production from the field will reach to 3.6 Tcf per year.
In 2011, Qatar will reach to the annual production capacity of 8 Tcf per year, while in that year Iran’s production will reach to 4 Tcf per year.
If Iran could implement all of its South Pars planned development projects on time, then it would reach the production capacity of 8 Tcf per year, not earlier than 2015.
Most important impact of delays and lower production in Iranian side would be migration of gas to the Qatari part and loss of condensate yield due to decrease of the field pressure.
South Pars Pics
South pars photo photo gallery
North Dome Development
The North Dome also known as North Field, was discovered in 1971,with the completion of Shell's North West Dome-1 well.
Qatar began production from North Field phase one (Alpha) in 1989 at rate of 800 MMcf/d. Gas from North Field phase one has been primarily used for local demand, and injection into the Dukhan field.
Subsequent phases of the North field development provided feedstock to LNG plants at Ras Laffan industrial port.
Based on the current Qatar planned projects, production from North Dome Field may reach to 23 to per day by 2012, any further increase in the production level of the Qatari side of the field is subject to the result of the ongoing study by Qatar Petroleum which is supposed to be released in 2012.
The prospects for further growth in Qatari gas production beyond 2012 are clouded by the uncertainty created by a moratorium on new export projects, which was imposed in 2005 while the effect of existing projects on North Field reservoirs was studied.
In order to monetize North Dome’s vast resources of gas and liquids, Qatar has undertaken ambitious plans for establishment of the world’s biggest LNG and GTL industry:
Qatar’s LNG Industry
Qatar has two LNG companies called Qatargas and RasGas and both are located in the Ras Laffan Industrial Port on the coast of Persian Gulf.
Since 1997, Qatar has been exporting LNG from the North Field. In 2006, Qatar surpassed Indonesia as the world’s largest LNG exporter. Based on the massive gas resources of the field, Qatar is developing the world biggest LNG export facilities in order to reach the capacity of 77 MMt/y (3.8 Tcf/y) by 2012 (see table below).
Qatargas and RasGas are two different companies responsible for the Qataries LNG projects.
Qatar’s GTL Industry
Oryx GTL (Sasol)
The plant was commissioned in early 2007, as the first operational GTL plant in Qatar. The plant nameplate capacity is 34,000 bbl/d, however, the plant has faced technical problems and did not reach full capacity. Sasol, the plant operator, is planning to shut down the plant in 2009 to resolve the technical problems. The plant uses 330 MMcf/d of gas from the Al Khaleej Gas project. The Oryx GTL project uses Sasol's Slurry Phase Distillate (SPD) process.
Pearl GTL (Shell)
The project is under construction and will be the world's largest GTL plant which will have the capacity of 140,000 bbl/d of Middle Distillates and significant quantities of LPG and condensate. The first of two 70,000 b/d GTL trains is planed to start production in 2011. Around 1.6 Bcf/d of f gas will be supplied from the North field to the project. Shell has 100% of the equity in the integrated upstream and plant project.
Table 3-North Field Production Plan ( Million Cubic Feet per Day).
| Project | Start Up | 1997 | 1998 | 1999 | 2000 | 2001 | 2002 | 2003 | 2004 | 2005 | 2006 | 2007 | 2008 | 2009 | 2010 | 2011 |
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| QatarGas | 1997 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | 860 | | QatarGas | 1998 | | 430 | 430 | 430 | 430 | 430 | 430 | 430 | 430 | 430 | 430 | 430 | 430 | 430 | 430 | | QatarGas | 2003 | | | | | | | 700 | 700 | 700 | 700 | 700 | 700 | 700 | 700 | 700 | | QatarGasII | 2008 | | | | | | | | | | | | 1700 | 1700 | 1700 | 1700 | | QatarGasII | 2009 | | | | | | | | | | | | | 1700 | 1700 | 1700 | | QatarGasIII | 2009 | | | | | | | | | | | | | | 1700 | 1700 | | QatarGasIV | 2009 | | | | | | | | | | | | | | | 1700 | | RasGas | 1999 | | | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | 1400 | | RasGas | 2004 | | | | | | | | 1000 | 1000 | 1000 | 1000 | 1000 | 1000 | 1000 | 1000 | | RasGas | 2005 | | | | | | | | | 1000 | 1000 | 1000 | 1000 | 1000 | 1000 | 1000 | | RasGas | 2007 | | | | | | | | | | | 1000 | 1000 | 1000 | 1000 | 1000 | | RasGas | 2008 | | | | | | | | | | | | 1700 | 1700 | 1700 | 1700 | | RasGas | 2010 | | | | | | | | | | | | | 1700 | 1700 | 1700 | | Al Khalij | 2005 | | | | | | | | | 650 | 650 | 650 | 650 | 650 | 650 | 650 | | Dolphin | 2007 | | | | | | | | | | | 2800 | 2800 | 2800 | 2800 | 4000 | | Pearl GTL | 2009 | | | | | | | | | | | | | 1700 | 1700 | 1700 | | Total MMcf/d | | 860 | 1300 | 2700 | 2700 | 2700 | 2700 | 3400 | 4400 | 6000 | 6000 | 9840 | 13240 | 18340 | 20000 | 23000 |
Table Sources: QatarGas, RasGas, Qatar Petroleum and internet
See also
Other Sources
tp://www.eia.doe.gov/emeu/cabs/Qatar/pdf.pdf Qatar: Country Analysis 2007] - Energy Information Administration - (Adobe Acrobat *.PDF document)
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