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Collaborating Authors
Petrochemicals
Abstract. This paper briefly discusses the current status and expected trends of the economies of the Central-East European countries and -gives an overview about the recent developments and future prospects for capitalising expansion of the oil industries in the region. In the past generally large state-run conglomerates held monopolistic positions in the oil industries. Since the early 1990's the downstream sector has undergone a period of significant restructuring. Most of the oil companies were reorganised and became joint stock companies which are either fully state owned or have already been partially privatised. Some countries have profoundly modified the legal framework of the energy sector but sometimes excessive bureaucracy, confusion on responsibilities, rapid regulatory changes or delay in decision making are still the main barriers to the privatisation process. The main challenge to the Central-East European Downstream industry is to stabilise its position in this transition environment, react quickly and efficiently to the changes, build up more effective marketing infrastructure and apply the European Union environmental and product quality standards. Attraction of foreign capital for investment is essential for many companies. The state can facilitate this process with a more consistent, stable taxation and legislation system in accordance with the EU norms. I. INTRODUCTION Since 1989 significant and non-reversible changes have taken place in the political, economic and social life of the Central-European countries but still many challenges have to be faced on the path leading from a centrally planned economy towards a free market economy. These countries inherited diverse states of economic development and the pace of the undergoing changes are also very different. Therefore the current transition period is quite uneven in these countries and the region is not homogeneous. The countries of this formal ‘block’ achieved remarkable results by remodelling their economy into a more market oriented system by restructuring their production and ownership pattern, furthermore by creating modern legislation and institutions which are needed for a market economy. Even so the whole transition period is remarkably uneven in this group, the speed of the changes are quite different. But while the situation is diverse, most of the countries in the region have a common objective to become members of the European Union. Hopefully these prospects will act as a stimulus to further economic progress and reforms. For this task some of these countries established a regional co-operation forum, the CEFTA (Central European Free Trade Agreement, actually integrating the Czech Republic, Hungary, Poland, Slovakia, Slovenia and more recently Ro
- Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.69)
- Europe > Slovakia (0.89)
- Europe > Czech Republic (0.89)
Abstract. Corrosion leading to pipe failure went unnoticed, despite the vigilance of highly qualified inspection agents, and caused a major refinery accident. This event has given rise to a review of the elements that condition the reliability of inspection: Non Destructive Testing (NDT), Inspection Planning and Quality Assurance. Among the wide range of existing NDT methods, emphasis is placed on those offering high potential for progress, such as the following: Intelligent pigging for pipelines, ultrasound devices used for reactors and tanks, and related developments in data acquisition and processing. To optimize Pipe Inspection Planning, methodology guidelines have been developed with a critical matrix that factors in both the probability and the consequence level of failure. In Quality Assurance, one example of recent headway is a Quality Assurance Inspection Handbook for pressure equipment, modelled on the quality standard IS0 9002. Overall, it should be remembered that the quality of an inspection service relies on human competence. No matter how well supported by specific certificates, this competence must first and foremost be based on sound experience as well as personal assets that include powers of observation, rigour, honesty and good sense. 1. A MAJOR ACCIDENT In 1992, the rupture of an 8 in. (200 mm) pipe in a refinery resulted in six fatalities, damages amounting to $300000000, and a shutdown to the different facilities for 12–18 months. The cause of this failure was corrosion4orrosion that had not been detected despite a very elaborate pipe inspection system backed by 20yr of data recorded on the same installation (Fig. 1). 2. INSPECTION AND PREVENTION The purpose of equipment inspection, among other means of prevention, is to reduce losses-the loss of human lives, damage losses, on property and environmental resources, production losses, dollar loss, even loss in image and reputation-and especorroded by pass i leak of LPG i FCC u Absorber stripper 2' Fig. 1. Disastrous consequences from a corroded pipe. cially to prevent major accidents and catastrophes. As the accident mentioned earlier shows, a very small cause can have very large consequences. Inspection service plays a crucial role in petrochemical industry insuring safety and reliable operation. A pipe rupture is classified as ‘equipment failure’. This label is too succinct and provides no useful information that might serve to improve prevention. Thorough analysis does: a rational method such as cause tree analysis makes it possible to identify all possible causes of failure. In the case at hand, an operational error can be excluded since it was established that the pipe was corroded. We are clearly dealing with a problem of inadequate awareness of the state of the equipment. Insight as to the state of equipment requires a combination of different means: -
- Law (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.88)
[RFP]2 Site Remediation Technology Advances
Gossen, R. G. (Canadian Occidental Petroleum Ltd., Calgary, Canada) | Hardisty, P. E. (Komex Clarke Bond Ltd., Bristol, UK) | Benoit, J. R. (AGRA Earth Sciences, Japan) | Dabbs, D. L. (Birch Mountain Resources Ltd., Calgary, Canada) | Dabrowski, T. L. (Komex International Ltd., Calgary, Canada)
Abstract. Technologies for the clean-up of soil and groundwater contamination from petroleum industry activities have advanced considerably over the past decade. This has been the result of increasing regulatory pressures in many parts of the world, mounting liability exposure, changing public perceptions, and the drive towards enhanced cost-effectiveness of remediation. This paper examines the state of remedial technologies used for petroleum industry applications in ex-situ and in-situ conditions, and includes case studies drawn from various locations around the world. Ex-situ technologies have evolved considerably from the simple excavationand-landfill approach still favoured in many places. On-site solutions, designed to destroy, encapsulate or immobilize contaminants are now increasingly favoured. These include methods such as pyrolysis, solvent extraction, oxidation/reduction, and bioremediation, designed to remediate the soil to acceptable standards. in-situ technologies have gained wide acceptance in the past several years as cost-effective alternatives to excavation-based (exsitu) methods. Application of in-situ methods involves alteration of sub-surface flow, pressure, chemical or biological regimes to achieve containment, redirection, removal or destruction of contaminants. Examples of specific in-situ technologies include soil vapour extraction, bioventing, biosparging, and the use of horizontal wells and semi-passive barrier systems. The decision to remediate a contaminated site and which technologies to apply, hinges on a sound understanding of the nature of the problem, the associated risks, and the economics of the proposed solution. The optimal remedial approach depends on achieving a balance among often competing societal factors, economic, social, environmental, cultural and political. INTRODUCTION There are two man-made features visible from space. One is the Great Wall of China. The other is the Syncrude Oil Sands tailing ponds in Alberta, Canada. These two human endeavours not only serve to demonstrate human presence on our planet, but also the societal context within which they are viewed. The Great Wall is a structure of considerable historical and cultural significance, worthy of preservation and restoration. The Oil Sands tailing ponds are the result of energy exploitation on a massive scale, which has provided significant benefits to Canadians. Nevertheless, the ponds present an environmental challenge, requiring some form of remediation. As the world moves into a new millennium, the need to protect our environment and natural resources grow ever more important
- North America > United States (1.00)
- North America > Canada > Alberta (0.35)
Abstract. A methodology for preparing an environmental inventory of sensitive marine natural resources will be described and the results presented in the Poster. This methodology is referred to as the Marine Resource Database. A method for Environmental Risk Assessment (ERA) applied offshore will be presented and the relationship between the environmental inventory and the data used in the ERA will be described. Specific methods for quantifying environmental risks and identification of environmental efficient measures associated with offshore installations and marine transportation will also elaborated. Practical application will be demonstrated with case studies from the North Sea. Abstract. This paper presents laboratory and field experiments for soil recovery done in oil field areas to replace the old procedure of contaminated soil disposal. The field trials began on two sites in 1995 using established agrotechnical practices and amendments. The tests were extended to other two locations in 1996 where some new amendments were introduced. - Restoring of soil texture and permeability affected by clay dispersion induced by brine contamination. - Biodegradation of existing oil sorbed on organic matter and clay and as a free phase in pores. The first two field applications were started with the sampling program for chemical and pedological site evaluation. Samples were analysed for pH, conductivity, organic matter, total N, mobile P and K, dissolved and exchangeable ions and total petroleum hydrocarbons (TPH). The first stage of field work (1995) included: scarification, applications of Ca amendments (gypsum or calcium gluconate), organic and inorganic fertilisation, cross harrowing, seeding with sunflower or barley, second fertilisation and harrowing. The soil analysis program revealed moderate improvement of saline and TPH parameters on surface layer. On the second stage of field work (1996), the previous program was modified according to the soil analysis data. In 1996 we started the recovery program for other two sites- both contaminated with oil and brine. The analysis performed on soil samples were extended as follows: - Characterisation of hydrophobic organic compounds (HOC) in order to evaluate the biodegradation process. We used two extraction procedures-Soxhlet and Supercritical Fluid Extraction (SFE)lp3. The Soxhlet extract was fractionated in four class products-saturate, aromatics, nitrogen-sulphur-oxygen (NSO) and asphaltenes as described in Ref. 4. The SF
- North America > United States (0.48)
- Europe > United Kingdom > North Sea (0.25)
- Europe > Norway > North Sea (0.25)
- (2 more...)
Abstract. Asia's dependence on Mideast oil, which was 74% in 1994, is likely to climb up to nearly 90% by 2010. In Asia, where soaring oil demand is likely but scant production increases can be expected, incremental oil import needs in 2010 will be some 10 million B/D (1.6 Mm3/d) most of which must be covered by Mideast oil. In East Asia (China, Asian NIES, ASEAN), oil demand will increase from 6.9 million B/D (1.1 Mm3/d) in 1992 to 14.9 million B/D (2.4 Mm3/d) in 2010 or 4.4%/yr. However crude oil production will increase from 5.4 million B/D (0.86 Mm3/d) in 1992 to 6.0 million B/D (0.95 Mm3/d) in 2010 at only 0.6%/yr. So oil import in East Asia will increase from 1.5 million B/D (0.24 Mm3/d) in 1992 to 8.9 million B/D (1.42 Mm3/d) in 2010 or 10.3%/yr. 1. ASIA'S GROWING OIL IMPORTS AND ITS INCREASING IMPORTANCE FROM INTERNATIONAL PERSPECTIVES Oil imports by Asia (excl. Japan) from outside the region, modest at 500 million B/D in 1992, are likely to increase to 15 million B/D by 1020. It means Asia's weight in the world's oil imports would almost double from 15.2% of 33 million B/D in 1992 to 28.3% of 53 million B/D in 2010. Of the world's primary energy supply, oil imports are likely to occupy 27% in 2010, up from a mere 14% in 1992. In Asia's regionwide primary energy supply, the share of oil imports is also expected to swell from 17% in 1992 to 25% by 2010. Faced with soaring oil dependence in this way, Asia would have no choice but to depend on Mideast oil to cover the greater part of incremental oil imports. See Table I. 2. OIL SUPPLY AND DEMAND IN CHINA Oil demand in China will increase from 2654 thousand B/D in 1992 to 6466 x lo3 B/D in 2010 5.1%/ yr. Crude oil production will increase from 2886 x lo3 B/D in 1992 to 3880 x lo3 B/D in 2010 at only 1.7%/yr. Oil trade will change from 232 x lo3 B/D exports in 1992 to 2586 imports in 2010. See Table II. GNP per capita will increase from 423 US dollars in 1992 to 1336 US dollars in 2010 at 6.6%/yr. Car possession will expand from 6 per 100 people to 54 in 2010 at 13.3%/yr. Of China's product demand in 1992-2010, it is white oils that grow high; gasoline up 8A%/yr, naphtha up 7.9%/yr, kerosene up 5.2%/yr, and diesel up 4.Í%/yr. The combined share of these white oils would rise from 60.2% in 1990 to 76.7% in 2010. TABLE I Oil Imports (% of the world total) and their shares in the primary energy supply Oil imports and shares in the world total million B/D ("Yi) Shares of imported oil in the primary energy supply (%) 1992 2010 1992 2010 Asia (excl. Japan) 5.0 (15.2) 15.0 (28.3) 17 Japan 5.4 (16.4) 6.2 (11.7) 58 u. s. 8.0 (24.2) 14.0 (26.4) 16 Europe 10.0 (30.3) 12.0 (22.6) 29 Others 4.6 (13.9) 5.8 (11.0) 21 25 50 2
- Energy > Oil & Gas > Downstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.51)
- Production and Well Operations (0.96)
- Management > Energy Economics (0.93)
Abstract. It is now largely accepted that natural gas will play a major and growing role in supplying future world primary energy needs. This energy source is gradually taking up a better position worldwide in an increasing number of consuming countries. Indeed, its intrinsic qualities combined with an abundance of resources give it priority in energy demand scenarios, especially in the power generation sector. The unequal distribution of gas resources on the earth and the gradual remoteness of the most recent discoveries will lead obviously to a tremendous increase in the international gas trade. The setting up of an adequate production and transportation infrastructure will bring huge investments to make gas available to most consuming markets and also the less endowed with gas resources. Therefore, it will be necessary not only to finance those projects, but also to develop these reserves at the least expensive cost in order to preserve gas competitiveness with other energy sources. Technological progress, and also new industrial approaches have to be strengthened and encouraged. Furthermore, a closer cooperation between all partners will open greater prospects for this energy promised to a bright future. 1. INTRODUCTION During the last 15 yr, world energy demand grew by 21% and, in the same period, gas demand increased by 46%. Indeed, natural gas was the fastest growing fossil fuel. By 2010, world energy demand is projected to increase again rapidly by 30-40%, and the fossil fuels share is expected to remain relatively stable at 90%. For both technological and environmental factors, a further significant increase in the use of gas is expected in the future. However, competition with oil and coal for both prices and funds will be the challenge that the gas industry will have to face. In the past, this industry has shown its ability to adapt to new constraints. It must follow this successful way in the future. 2. WORLD NATURAL GAS DEMAND TRENDS After more than two decades of steady and sustained growth, worldwide natural gas demand shows bright prospects for further expansion. Natural gas share in world energy balances is expected to increase up to 25% by 2010, compared with 23% in 1995. Indeed, environmental issues and a growing awareness of ecological problems favour the gas option. Natural gas is seen as a clean fuel, with powerful and appreciated assets when compared with other fossil fuels. See Fig. 1. In addition, the increase in the use of gas is closely linked to the performances of gas technologies, mainly in the power generation sector where the use of gas in combined cycle power plants and in cogeneration is developing rapidly. Better efficiency, lower production costs and plant investments as well as greater flexibility of use are some of the advantages that give gas a determinant position when compared to its competing energy sou
- Europe (1.00)
- North America (0.68)
- Asia > Middle East > Qatar (0.28)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > West Siberian Basin > South Kara/Yamal Basin > Bovanenkovskoye Field (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Indonesia > Natuna Sea > Sarawak - East Natuna Basin > Natuna Field (0.99)
- (3 more...)
- Management > Asset and Portfolio Management (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- Health, Safety, Environment & Sustainability > Environment (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Abstract. This poster session focuses on processing options to condition natural gas for pipeline transport and use as a feedstock for petroleum refinery and petrochemical processing. New advances in technology make this route for converting low-value gas to high-value end products economically attractive. Technologies to remove carbon dioxide, hydrogen sulfide, water, and mercury are highlighted. Innovative membrane systems, inhibited amines, promoted hot potassium carbonates, advanced formulated solvents, high-performing physical solvents, and specialized molecular sieve adsorbents are compared and contrasted. The influence of processing conditions and product specifications on technology selection are illustrated. The application of these technologies in a typical natural gas plant is shown. The availability of these natural gas treating innovations allows the end user to adequately and economically condition the gas for pipeline transport or further downstream processing. INTRODUCTION Natural gas must meet certain process specifications before it can be delivered to a pipeline for transport to its destination. The particular specifications are dependent on the end use. For example, the gas intended for petrochemical processing is different from that intended for household heating. In general, however, free liquid water and liquid hydrocarbons must be removed, as well as some additional heavy hydrocarbon removal, to control dew point and heating value. Furthermore, most natural gases contain acid gases such as carbon dioxide and hydrogen sulfide in varying amounts and ratios. These gases are highly corrosive to transport pipelines and processing equipment, especially in combination with water, and must be removed to meet end-user specifications. Hydrogen sulfide is also toxic and must be removed to levels well below that of other acid gases. The concentrated CO, removed from the natural gas may usually be released into the atmosphere, depending on local air quality regulations, or it may be used as low-grade fuel gas if it has a sufficient hydrocarbon content. In enhanced oil recovery operations, CO, is a desired product and is reintroduced into the well for increased oil recovery. If sufficient H, S is removed, it will usually have to be converted to solid or liquid sulfur or other sulfur compounds because of its toxicity. The poster lists typical end-use specifications for items such as CO, H2S, H20 and Hg contents, dew point, and heating value, as well as the basis for these specifications. A typical treatment sequence includes coarse filtration, dehydration, impurity removal, water and hydrocarbon dew-point control, nitrogen rejection, and acid gas removal. Side treatments include acid gas treatment, such as H2S conversion, and natural gas liquid (NGL) stabilization. The poster includes a diagram showing the
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Health, Safety, Environment & Sustainability > Health > Noise, chemicals, and other workplace hazards (1.00)
- Facilities Design, Construction and Operation (1.00)
Abstract. At present the China natural gas industry has significant development. The accumulated proved gas reserves are 1124.57 G m3, the accumulated proved solution gas reserves are 826.64 G m3 up to 1995. The production of natural gas in China is 16.13 G m3. The approach for developing China's natural gas industry is as follows: - Strengthen exploration Enhance deep formation exploration in old fields in eastern areas in China. Expand exploration in central and western areas such as Shichuan, Shanganning, Qinghai and Xinjiang. Speed up exploitation of Shanganning gas fields and Shichuan gas fields Speed up exploitation of Xingiang condensate field Expand usage of natural gas for residences gradually Apply natural gas for automobile properly Use natural gas for power generation in order to reduce pollution in some areas if conditions allow. - Speed up exploitation - Utilization of natural gas - Develop petrochemical industry and produce fertilizer and methyl alcohol. The tentative plan to develop the China natural gas industry Stabilize crude oil production while speeding up development of natural gas - Insist on the policy of ‘equally emphasizing oil and gas’ - Strengthen regional cooperation In the meantime enhance the exploitation of domestic natural gas, strengthen the cooperation with Middle Asia, Russia and surrounding countries - Establish a natural gas transportation network Make an overall plan of a gas transportation network considering both domestic resource and resource from the surrounding countries. The gas transportation network will be a flexible and reliable system linked to many gas fields and consumers. I NT R O D U CTI O N China is a country that began utilization of natural gas long ago in history. Since 1949, the Chinese natural gas industry has been greatly improved. In addition to Sichuan gas fields, some oil fields, such as Daqing and Shengli, can also produce a large volume of associated gas. Even so, since the natural gas industry of China was established on a weak base, the natural gas is still in the initial stage in energy consumption, and the natural gas development and facility construction often lag behind because of the lack of gathering, transportation and storage facilities which limits the development and utilization of natural gas and the requirement that the gas production must keep pace with the downstream construction. Because all the gas fields discovered so far are not located in or near the gas market, the conditions of gas gathering, transportation and storage have to be considered first sufficiently. The gas fields discovered so far produce both pure gas and condensate, and as a result, light hydrocarbons, in addition to methane, should also be utilized because they can be used not only as high-quality fuel but also as important chemical raw materials. M
- Asia > China > Sichuan Province (0.36)
- Asia > China > Heilongjiang Province > Daqing (0.25)
Abstract. The abundance of natural gas in various parts of the world and the environmental need for recovering associated gas from crude oil production has made focusing on the utilization of natural gas a necessity. For many years, scientists at academic and industrial research institutions have been working on the direct and indirect conversion of methane (natural gas) to higher hydrocarbons. Because these processes for methane conversion require significant capital investment, the key to success of such developments depends on the value of the products obtained. In other words, the products that are produced must be significantly more valuable than transportation fuels. At an average value of $500/MT, ethylene and propylene are valued at twice the gasoline value of $250/MT. An indirect route for gas with greater than 99% conversion of methanol, 80 mol-% selectivity to ethylene plus propylene, and total C,-C, olefin selectivity of 9 mol-% can be achieved. This methanol conversion route for the production of ethylene and propylene is significantly more attractive than the conventional naphtha cracking route or other methanol-to-olefin and gasoline options. This poster describes the development, process design, and economics of the UOP/HYDRO MTO process and compares it with other methane-conversion options. INTRO DU CTIO N When natural gas is abundant in remote locations, its value is low, and the transportation costs may be so high that it is either left undeveloped, flared, or reinjected. However, this natural gas can be converted to high-valued products such as ethylene and propylene. Figure 1 shows a strong economic driving force to produce ethylene and propylene from natural gas because ethylene and propylene are valued at twice the value of gasoline and roughly four times the value of naturai gas. The UOP/HYDRO process converts methanol to light olefins, primarily ethylene and propylene. The MTO process is the missing economical second step of a two-step conversion of natural gas to olefins (GTO). The GTO scheme is shown in Fig. 2. In GPO processing, the natural gas is converted first to methanol and then to ethylene and propylene. The UOP/HYDRO MTO process has greater than 99% conversion of methanol, 80% selectivity to ethylene and propylene, and a total C2-C, olefin selectivity of 93 mol%. Table 1 shows the material balance for MTO, GTO and naphtha cracking. The UOP/HYDRO MTO process uses MTO- looTM catalyst, a proprietary UOP catalyst containing SAPO-34 material. The process employs a fluidized-bed reactor and regenerator to facilitate frequent catalyst regeneration and provide good temperature control. UOP and Norsk Hydro have demonstrated that the catalyst is stable even after more than 450 cycles of reaction and regeneration. The two companies have also demonstrated the MTO process in a large demonstration scale
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas (1.00)
Abstract. This presentation summarizes some of our experiences from commissioning and start up of the Statoil/Conoco methanol plant at Tjeldbergodden on the Norwegian west coast. The front end section of the plant is based on Combined Reforming which is characterized by the introduction of a secondary oxygen blown reformerdownstream of the conventional steam reformer. Major problems have been reported from startup and operation of other plants based on the same technology. The raw materials for the plant is natural gas from an offshore oil field with large quantities of associated gas. Due to strict environmental regulations in Norway on emissions of greenhouse gases, the methanol plant has been designed as the most energy efficient and environmental friendly in the world. BACKGROUND The Statoil/Conoco Methanol Plant at Tjeldbergodden, is a direct result of the discovery of the Heidrun Oil Field on the Halten Bank, 175 kilometres off the Mid Norwegian coast. The Heidrun Oil field was discovered in 1985 and declared commercial in the following year. The oils field contains large quantities of associated gas which cannot be flared due to strict environmental regulations in Norway on emissions of greenhouse gases. All Natural Gas developed in the Norwegian and British sector of the North Sea has so far been transported to Western Europe through offshore pipelines. The Heidrun Field was located in a new offshore sector further north and far away from the existing pipeline infrastructure. The gas had to be converted into a transportable liquid or reinjected in the oil field. Statoil and Conoco evaluated a number of alternatives and concluded in 1990 that the best economic alternative was to build a pipeline to Tjeldbergodden and build a methanol plant. In 1991 the Norwegian parliament (Stortinget) approved development of the Heidrun Field. In February 1992 Stortinget approved the Tjeldbergodden landfall and methanol production. HEIDRUN OFFSHORE FIELD Heidrun is being produced in 350 metres of water by the world's first concrete-hulled tension leg platform. This floating unit attaches to the seabed foundation with the aid of metal tethers. The oil field contains 45 billion Sm3 of associated Natural Gas. The methanol plant consumes 700 million Sm3 per annum. THE PIPELINE The 16 inch ‘Haltenpipe’ able to carry up to 2.2 billion Sm3 of gas per year. The pipeline is 250 km long and delivered the first gas to Tjeldbergodden on Dec. 11, 1996. Design pressure for the pipeline is 190 bar, with maximum operating pressure of 185 bar. METHANOL PLANT The methanol plant is designed for a capacity of 830 O00 MTPY (2400 MTPD) which represent the world largest single train methanol plant. Statoil is responsible for constructing the plant and for its subsequent operation. The facility was completed early in 1997, and to start delivering methanol in second
- Europe > Norway > Norwegian Sea > Halten Terrace > Block 6507/8 > Heidrun Field > Åre Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > Block 6507/8 > Heidrun Field > Tilje Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > Block 6507/8 > Heidrun Field > Ile Formation (0.99)
- (5 more...)