Saturday, March 20, 2010
Saturday, March 6, 2010
Thursday, November 19, 2009
Interesting link
Dear All,
Please read the following links: http://www.carbonet.net/bjarne/Stoupakova%20et%20al%202006.swf
Thanks
Please read the following links: http://www.carbonet.net/bjarne/Stoupakova%20et%20al%202006.swf
Thanks
Saturday, November 14, 2009
MPD in Timor Sea drilling campaign
The International Association Drilling Contractors (IADC) defined the Managed Pressure Drilling (MPD) is an adaptive drilling process used to precisely control the annular pressure profile throughout the wellbore. The objectives are to ascertain the downhole pressure environment limits and to manage the annular hydraulic pressure profile accordingly.
MPD is a new drilling technique that using up-to-date technology to have a quick responds to the drilling problems or another word is that to prevent the drilling problems such as Kick, stuck pipe and lost circultion to occur during drilling.
Kick occurs when the wellbore pressure is less than pore pressure that causes hydrocarbon (HC) fluids flow into the wellbore and toxic gas (i.e. H2S) or fluid may migrate into the surface via annulus, the kick is something that the operators and contractors not wish to happen because if it happens beside hazardous to the well and crews and also it incurs the Non-Productive Time (NPT) hence the drilling cost will be expensive, engineers and researchers are working vigorously find ways how to minimize the NPT associated with the drilling problems. In addition, the stuck pipe occurs when the formation is migrated at the vicinity of wellbore which cause ballooning in the wellbore where the drilling cutting consist of fragmented rock, fine-sands, silt, clays and shale accumulated at the annulus making it is hard the drilling mud/fluids to lift the cuttings to the surface, this normally occurs in horizontal wells when the Bottomhole Assembly (BHA) is moving downward inclination that making rather difficult for mud circulation. Another drilling problems is that lost circulation, as said before the kick occur when the wellbore pressure less than the pore pressure, however in the case of lost circulation is when the wellbore pressure is greater the fracture pressure. Fracture pressure is the limit of the well's ability to bear to the certain pressure. When the lost circulation occurs the expensive drilling mud will flow into the formation hence drilling cost on the drilling mud will be increased and the well cleaning will not effective hence the NPT increases.
The Managed Pressure Drilling (MPD) can be used to mitigated these problems by applying the surface pressure, the MPD is provide a closed pressure circulation vs. open to atmosphere in conventional drilling. There are various types of variants MPD, Constant Bottomhole Pressure (CBHP), Pressurized Mud Cap Drilling and Dual gradient. Dual Gradient is suitable for deep water operation in offshore environment. As exploration drilling in Joint Petroleum Development Area (JPDA) going on in Timor Sea, so it is recommended the company to use the MPD in drilling operation in order to make impossible to be a possible one. PETRONAS has been using MPD in their exploration drilling in one block in JPDA.
It is good for the regulator of Timor Leste to look into the MPD application and recommend to the industries in order to achieve the successful drilling that all parties want. As a researcher and designer on MPD I have no doubt with its application.Evidences have prevailed the successful of the drilling operation.
MPD is a new drilling technique that using up-to-date technology to have a quick responds to the drilling problems or another word is that to prevent the drilling problems such as Kick, stuck pipe and lost circultion to occur during drilling.
Kick occurs when the wellbore pressure is less than pore pressure that causes hydrocarbon (HC) fluids flow into the wellbore and toxic gas (i.e. H2S) or fluid may migrate into the surface via annulus, the kick is something that the operators and contractors not wish to happen because if it happens beside hazardous to the well and crews and also it incurs the Non-Productive Time (NPT) hence the drilling cost will be expensive, engineers and researchers are working vigorously find ways how to minimize the NPT associated with the drilling problems. In addition, the stuck pipe occurs when the formation is migrated at the vicinity of wellbore which cause ballooning in the wellbore where the drilling cutting consist of fragmented rock, fine-sands, silt, clays and shale accumulated at the annulus making it is hard the drilling mud/fluids to lift the cuttings to the surface, this normally occurs in horizontal wells when the Bottomhole Assembly (BHA) is moving downward inclination that making rather difficult for mud circulation. Another drilling problems is that lost circulation, as said before the kick occur when the wellbore pressure less than the pore pressure, however in the case of lost circulation is when the wellbore pressure is greater the fracture pressure. Fracture pressure is the limit of the well's ability to bear to the certain pressure. When the lost circulation occurs the expensive drilling mud will flow into the formation hence drilling cost on the drilling mud will be increased and the well cleaning will not effective hence the NPT increases.
The Managed Pressure Drilling (MPD) can be used to mitigated these problems by applying the surface pressure, the MPD is provide a closed pressure circulation vs. open to atmosphere in conventional drilling. There are various types of variants MPD, Constant Bottomhole Pressure (CBHP), Pressurized Mud Cap Drilling and Dual gradient. Dual Gradient is suitable for deep water operation in offshore environment. As exploration drilling in Joint Petroleum Development Area (JPDA) going on in Timor Sea, so it is recommended the company to use the MPD in drilling operation in order to make impossible to be a possible one. PETRONAS has been using MPD in their exploration drilling in one block in JPDA.
It is good for the regulator of Timor Leste to look into the MPD application and recommend to the industries in order to achieve the successful drilling that all parties want. As a researcher and designer on MPD I have no doubt with its application.Evidences have prevailed the successful of the drilling operation.
MPD project phase I finished
The managed Pressure Drilling (MPD) project phased I has been done, and for future plan will be emphasize on the simulation and proposing to the drilling industries and operators. I wish the project achieved its objective.
Sunday, October 11, 2009
Today’s petroleum industry
As the world energy reported that during 2005, petroleum fossil fuels met about 80 per cent of the world’s demand for transportation fuels and nearly half the world’s primary energy demand. Petrol, diesel, LPG (liquefied petroleum gas) and CNG (compressed natural gas) are the most common petroleum products used in cars, trucks, trains and buses. In many parts of the world, petroleum fuels are used in power stations to generate electricity for industries and for providing heating and air conditioning needs. Kerosene and LPG are bottled and used in homes in some parts of the world for cooking and heating.
Petroleum and natural gas are Australia’s two most valuable resource exports. Crude oil accounted for about 35 per cent of Australia’s primary energy consumption in 2004/2005, according to The Australian Bureau of Agricultural and Resource Economics. Natural gas sources filled 19 per cent of primary energy needs in Australia. Western Australia has risen to prominence as Australia’s leading oil-producing state. In 2005, Western Australia had 67 producing oil fields and led the nation in gas and LNG (liquefied natural gas) production. Petroleum (crude oil, condensate and natural gas) had become the leading contributor to the state’s resources sector. Crude oil and condensate production averaged 0.052 gigalitres per day (328,000 barrels per day). Average gas production was 0.072 giga cubic metres per day. Petroleum products accounted for more than one third of the value of WA’s mineral and energy production.
However, the oil and gas industry is at the cusp of significant change, with a number of countries believed to have passed their oil production peak, signalling an impending tightening of supply in the coming decades. While no-one is certain, some believe that at our present rate of consumption, the world has around 50 years of crude oil and more than 70 years of natural gas reserves. In recent decades, Australia has been around 80% to 85% net self-sufficient in oil, but this will fall to around 50% by 2020, according to the Commonwealth Scientific and Industrial Research Organisation (CSIRO). The Western Australian Office of Energy predicts that our state’s crude oil and condensate will sustain a further 25 years’ consumption at current production levels.
Large regions that are offshore Australia remain lightly explored, so there is a real chance of finding a new petroleum province. While some experts predict an imminent world oil shortage, other researchers say that significant, new oil fields will be discovered, particularly in Russia, the Caspian, Brazil, Angola and Canada.
New energy opportunities:
“Oil shale”, an “unconventional” oil source, presents opportunities to supply some of the fossil energy needs of the world in the years ahead. Most oil shales are fine-grained sedimentary rocks that yield substantial quantities of oil by heating and distillation. One tonne of oil shale contains more than 200 litres of oil. Total world resources of oil shale are conservatively estimated at 2.6 trillion barrels.
Australia has significantly large deposits of “proved oil shale in place”. In 1802, a French world scientific expedition discovered oil shale in New South Wales near the Blue Mountains. In 2005 it was estimated that there were 29 million barrels of oil shale economic demonstrated resources in Australia.
lso, there are other solutions to Australia’s problem of depleting transport fuels such as diesel oil. Importantly, international energy companies are exploring options to directly convert Australia’s abundant natural gas reserves into clean, non-polluting liquids, in the form of diesel or aviation fuels. This process is known as “Gas to Liquid”, or GTL.
The development of the Australian oil industry:
The first drilling carried out for the purpose of discovering oil was in the Coorong area of South Australia in 1892. Unfortunately, the shallow hole was dry. Later in 1900, the first petroleum discovery was made near Roma, Queensland, when a water bore intersected a natural gas field. Offshore, the first oil well was drilled in the Albany harbour in Western Australia in 1907. Australia’s first oil field was discovered at Lake Bunga near Lakes Entrance in the Gippsland Basin in 1924.
However, Australia’s commercial petroleum industry did not really commence until 1953. In November of that year, much excitement was generated by the discovery of oil at Rough Range in Western Australia. The discovery was made by West Australian Petroleum Pty Ltd (a joint venture between Ampol and Caltex) which began producing 550 barrels per day (a barrel contains about 160 litres) at Rough Range. Commercial production of petroleum on a large scale began on the Moonie oil field in Queensland in 1964. The search for petroleum intensified with widespread exploration and discoveries around Australia. One of the more notable finds included Barrow Island in the Carnarvon Basin, Western Australia, in 1964. Despite around 900 wells being drilled on Barrow Island, it has remained an “A” Class nature reserve.
The main petroleum discovery was made in the North West Shelf, located between 125 and 150 kilometres northwest of Dampier, Western Australia, in 1971. The North West Shelf (NWS) project has become Australia’s largest resource development. Operated by Woodside Offshore Petroleum, the NWS project consists of two major phases:
• The domestic gas phase, which supplies gas to Western Australia’s domestic market.
• The liquid natural gas (LNG phase), which supplies LNG for export primarily to Japan with other sales to the USA and Korea.
The NWS project also produces crude oil from the Cossack, Wanaea, Lambert and Hermea oil and gas fields, about 30 kilometres northeast of North Rankin. During the 2004 financial year, the NWS project produced 36.9 million barrels of crude oil, 36.9 million barrels of condensate, 186 billion cubic feet of domestic gas, 8.0 million tonnes of LNG and 744,600 tonnes of LPG. For more information about natural gas and the North West Shelf Project.
Western Australia’s Griffin oil and gas project commenced in 1994 at the Carnarvon Basin, some 68 kilometres offshore from Onslow. The Griffin operator is BHP Billiton Petroleum. During the 2005 financial year, the project produced 3.9 million barrels of crude oil and 5.95 billion standard cubic feet of gas sales.
A new oilfield was discovered in 2003 on the offshore North West Cape near Exmouth. The new Stybarrow oilfield is jointly owned by BHP Billiton and Woodside, with BHP Billiton the operator. It is Australia’s deepest oil field development, with a water depth of about 825 metres. Stybarrow is expected to process about 80,000 barrels of liquids a day. First production is planned for the first quarter of 2008.
http://www.worldofenergy.com.au/factsheet_petroleum/07_fact_petroleum_refining.html
Petroleum and natural gas are Australia’s two most valuable resource exports. Crude oil accounted for about 35 per cent of Australia’s primary energy consumption in 2004/2005, according to The Australian Bureau of Agricultural and Resource Economics. Natural gas sources filled 19 per cent of primary energy needs in Australia. Western Australia has risen to prominence as Australia’s leading oil-producing state. In 2005, Western Australia had 67 producing oil fields and led the nation in gas and LNG (liquefied natural gas) production. Petroleum (crude oil, condensate and natural gas) had become the leading contributor to the state’s resources sector. Crude oil and condensate production averaged 0.052 gigalitres per day (328,000 barrels per day). Average gas production was 0.072 giga cubic metres per day. Petroleum products accounted for more than one third of the value of WA’s mineral and energy production.
However, the oil and gas industry is at the cusp of significant change, with a number of countries believed to have passed their oil production peak, signalling an impending tightening of supply in the coming decades. While no-one is certain, some believe that at our present rate of consumption, the world has around 50 years of crude oil and more than 70 years of natural gas reserves. In recent decades, Australia has been around 80% to 85% net self-sufficient in oil, but this will fall to around 50% by 2020, according to the Commonwealth Scientific and Industrial Research Organisation (CSIRO). The Western Australian Office of Energy predicts that our state’s crude oil and condensate will sustain a further 25 years’ consumption at current production levels.
Large regions that are offshore Australia remain lightly explored, so there is a real chance of finding a new petroleum province. While some experts predict an imminent world oil shortage, other researchers say that significant, new oil fields will be discovered, particularly in Russia, the Caspian, Brazil, Angola and Canada.
New energy opportunities:
“Oil shale”, an “unconventional” oil source, presents opportunities to supply some of the fossil energy needs of the world in the years ahead. Most oil shales are fine-grained sedimentary rocks that yield substantial quantities of oil by heating and distillation. One tonne of oil shale contains more than 200 litres of oil. Total world resources of oil shale are conservatively estimated at 2.6 trillion barrels.
Australia has significantly large deposits of “proved oil shale in place”. In 1802, a French world scientific expedition discovered oil shale in New South Wales near the Blue Mountains. In 2005 it was estimated that there were 29 million barrels of oil shale economic demonstrated resources in Australia.
lso, there are other solutions to Australia’s problem of depleting transport fuels such as diesel oil. Importantly, international energy companies are exploring options to directly convert Australia’s abundant natural gas reserves into clean, non-polluting liquids, in the form of diesel or aviation fuels. This process is known as “Gas to Liquid”, or GTL.
The development of the Australian oil industry:
The first drilling carried out for the purpose of discovering oil was in the Coorong area of South Australia in 1892. Unfortunately, the shallow hole was dry. Later in 1900, the first petroleum discovery was made near Roma, Queensland, when a water bore intersected a natural gas field. Offshore, the first oil well was drilled in the Albany harbour in Western Australia in 1907. Australia’s first oil field was discovered at Lake Bunga near Lakes Entrance in the Gippsland Basin in 1924.
However, Australia’s commercial petroleum industry did not really commence until 1953. In November of that year, much excitement was generated by the discovery of oil at Rough Range in Western Australia. The discovery was made by West Australian Petroleum Pty Ltd (a joint venture between Ampol and Caltex) which began producing 550 barrels per day (a barrel contains about 160 litres) at Rough Range. Commercial production of petroleum on a large scale began on the Moonie oil field in Queensland in 1964. The search for petroleum intensified with widespread exploration and discoveries around Australia. One of the more notable finds included Barrow Island in the Carnarvon Basin, Western Australia, in 1964. Despite around 900 wells being drilled on Barrow Island, it has remained an “A” Class nature reserve.
The main petroleum discovery was made in the North West Shelf, located between 125 and 150 kilometres northwest of Dampier, Western Australia, in 1971. The North West Shelf (NWS) project has become Australia’s largest resource development. Operated by Woodside Offshore Petroleum, the NWS project consists of two major phases:
• The domestic gas phase, which supplies gas to Western Australia’s domestic market.
• The liquid natural gas (LNG phase), which supplies LNG for export primarily to Japan with other sales to the USA and Korea.
The NWS project also produces crude oil from the Cossack, Wanaea, Lambert and Hermea oil and gas fields, about 30 kilometres northeast of North Rankin. During the 2004 financial year, the NWS project produced 36.9 million barrels of crude oil, 36.9 million barrels of condensate, 186 billion cubic feet of domestic gas, 8.0 million tonnes of LNG and 744,600 tonnes of LPG. For more information about natural gas and the North West Shelf Project.
Western Australia’s Griffin oil and gas project commenced in 1994 at the Carnarvon Basin, some 68 kilometres offshore from Onslow. The Griffin operator is BHP Billiton Petroleum. During the 2005 financial year, the project produced 3.9 million barrels of crude oil and 5.95 billion standard cubic feet of gas sales.
A new oilfield was discovered in 2003 on the offshore North West Cape near Exmouth. The new Stybarrow oilfield is jointly owned by BHP Billiton and Woodside, with BHP Billiton the operator. It is Australia’s deepest oil field development, with a water depth of about 825 metres. Stybarrow is expected to process about 80,000 barrels of liquids a day. First production is planned for the first quarter of 2008.
http://www.worldofenergy.com.au/factsheet_petroleum/07_fact_petroleum_refining.html
Subscribe to:
Posts (Atom)
