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Abstract. This paper focuses on the human aspect of environmental assessment and protection. Social and economic needs in the usually backward and remote oil producing regions of developing countries are acute. However, these regions normally do not participate in the formulation of oil exploration contracts. These are framed considering macroeconomic variables such as national self-sufficiency and balance of payments. Oil companies therefore are placed in the center of these conflicting forces. A remarkable feature of developing countries are interregional development disparities, generally described as center/periphery inequalities. The center, the metropolitan areas, is linked to international markets, absorbs and concentrates the most qualified human resources, the flow of information and business opportunities. The periphery, the physical and social scenario of oil operations, can generally be characterized as having low enducation and skill levels, a weak economic base, low productivity, weak government institutions and poor environmental management. Of all challenges faced by an oil operator when arriving in an isolated oil province, the most difficult is the permanent pressure by the community to get the company involved in activities and take responsibilities that, strictly speaking, belong to the government. The options are plain: ignore the pressure, concentrate on the contractual obligation related with production and its efficiency parameters, or develop and carry out a framework of integration with the community. The paper addresses these issues in the context of Occidental Petroleum's experience with the Cano Limón project in Colombia. The strategies and specific programs developed are presented, which include several major environmental initiatives. 1. INTRODUCTION Social and economic needs in the usually backward and remote oil producing regions of developing countries are acute. However, these regions normally do not participate in the formulation of oil exploration contracts. These are framed considering macroeconomic variables such as national self-suficiency and balance of payments. Oil companies therefore are placed in the center of these conflicting forces. This paper focuses on the choices available to an oil company that has to meet efficiency and profitability standards while integrating with isolated and possibly hostile communities which have been excluded from the formulation of National Oil Policy. Several examples of strategies are covered to illustrate specific responses to the various challenges created by the need to balance social integration and oil development. 2. THE OIL REGIONS-THE COLOMBIAN CASE (a) The center and the periphery One of the main structural proble
Abstract. Of the vast Russian oil resources, only one third is explored. A decline in production since 1987 has resulted not from reserve depletion, but from the general economic crisis and the deterioration of reserve quality, expressed in reduced flow rates due to the depletion of the largest fields, increase in water cut, decline in the size and productivity of new discoveries. Undiscovered oil resources of Russia account for 85-90% of the total former USSR resources, outstripping any other country but ranking below the joint resources of the Middle East countries. Most of the unexplored oil resources are concentrated in West Siberia, Arctic and Pacific sea shelf and East Siberia. Russian oil legislation is regulated by the Law on Subsurface Resources, Regulations of Exploration and Production Licensing and draft Law on Oil and Gas. The Law provides for exploration and production licensing on a ‘two keys’ basis, the license awards and terms settlement being executed jointly by local and central authorities. An obligatory supplement to the license is the License Agreement concluded by licensing authorities and the rightholder. The terms of the License Agreement correspond to the world experience of oil business. The Law gives vast opportunities for the settlement of mutually acceptable terms when licenses are obtained by competition, at bidding rounds or by direct negotiations. Russia is one of the largest oil producers in the world with a long and complicated history of the petroleum industry. At the beginning of the century, Russia accounted for half of the total world oil production. In 1911 crude production for the first time peaked at 11.5 MMt. After a drastic drop to 3.7 MMt in 1918, oil production started to grow again, peaking for the second time at 34 MMt in 1940. During World War II, oil production dropped for the second time. In the post-war period oil production in the USSR continuously increased until 1984. In 1985, production dropped again, but during 1986–1988 HC liquids production in Russia increased to 569.5 MMt, amounting to 624 MMt in the whole USSR. This was the third peak in the history of Russian oil industry. In recent years oil production showed a sustained decline. In 1993, oil and gas condensate production was about 355.4 MMt (Fig. 1). Is the third decline in oil production caused by depletion of oil resources? Or are there oil reserves sufficient to stabilize and increase oil production? And if so, what are the problems related to their development? The vast reserve base enabling Russia to be the world's leading oil producer was the result of exploratory efforts in West Siberia, Ural-Volga and other regions, performed mostly during 1950–1980s. Exploration activity was the highest during the last 30 years. This peri
- Europe > Russia (1.00)
- Asia > Russia > Siberian Federal District (0.25)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Samotlorskoye Field (0.99)
- North America > Canada > Quebec > Arctic Platform (0.95)
- North America > Canada > Nunavut > Arctic Platform (0.95)
- (2 more...)
[l]P5 New Petroleum Fields and Offshore Provinces in Russia
Khalimov, E. (Institute of Geology and Exploration of Combustible Fuels, Moscow) | Orudgeva, D. (Institute of Geology and Exploration of Combustible Fuels, Moscow) | Obukhov, A. (Institute of Geology and Exploration of Combustible Fuels, Moscow) | Lovelock, E. R. (Shell Internationale Petroleum Maatschappij, Netherlands)
Abstract. Russian sea shelves cover about 3.9 million sq. km (14% of total world area). The petroleum potential of the Russian shelves exceeds the hydrocarbon (HC) reserves of the North Sea more than tenfold. However, 82% of the HC resources of the Russian shelf are confined to the Arctic seas with an extremely severe environment (low temperatures, ice, high waves, storms and hurricanes, etc.). About 14% of the undiscovered resources lie in the Far East and 4%-in the Russian sectors of the Baltic and Caspian seas. Russian offshore HC resources are poorly developed. Oil reserves to resources ratio is about 1% in the Arctic seas and about 13% in the Far East seas. 30 oil and gas fields have been discovered and quite a few promising structures identified in the Russian sea shelves. Geologic structure and development conditions of the following fields are given in brief: Peschano-Ozerskoye (1982), Gulyayevskoye North (1986), Prirazlomnoye (1989) (the Barents Sea); Odoptu Offshore (1977), Chaivo Offshore (1979), Lunskoye Offshore (1984), Piltun-Astokhskoye (1986), Arkutun-Daginskoye (1989) (the Sea of Okhotsk). Oil discoveries are classified according to their commercial importance and development conditions. Oil production volume from new Russian offshore discoveries is forecasted. The importance of world experience, application of advanced technologies and up-to-date equipment for offshore oil exploration, production and drilling in Russia is evaluated. INTRODUCTION The total area of the offshore provinces of Russia including both the outer seas (Arctic and Far East) and the inner seas (Caspian, Baltic, Rlack Seas and Sea of Azov) amounts to nearly four million km2, or 14% of the world's shallow water offshore regions. The water depth at the edge of the shelves reaches 240 m while the width varies greatly from 5 up to 1350 km. Numerous depositional basins are to be found within this vast offshore area, of which the largest are as follows: - East Barents, South Kara, Laptev, East Siberian and Chukchi in the Arctic - Anadyr, Navarin, Khatyrka, Olyutorsk-Komandor, North Sakhalin, Okhotsk-Kamchatka and South Okhotsk in the Far East The oil and gas potential of Russia's offshore provinces is 6 times larger than that of the North Sea. However, 82% of its resources are located within the Arctic Seas which feature the most harsh climatic conditions (i.e. low temperatures, thick sea ice for most of the year, high waves and storm force winds etc.). The Far Eastern seas account for 14% of the potential resources while 4% is to be found in the Baltic, Caspian, Black Sea and Azov provinces. Most of the hydrocarbons remain undiscovered. So far only about 1% of the potential reserves in the A
- Europe > Russia > Northwestern Federal District > Nenets Autonomous Okrug (0.31)
- Europe > Russia > Northwestern Federal District > Komi Republic (0.31)
- Asia > Russia > Far Eastern Federal District > Sakhalin Oblast (0.28)
- Asia > Russia > Far Eastern Federal District > Chukotka Autonomous Okrug > Anadyr (0.25)
- Phanerozoic > Mesozoic > Cretaceous (0.51)
- Phanerozoic > Cenozoic > Neogene (0.49)
- North America > United States > Alaska > Bering Sea > Navarin Basin (0.99)
- Europe > Russia > Northwestern Federal District > Northwestern Federal District > Nenets Autonomous Okrug > Timan-Pechora Basin (0.99)
- Europe > Russia > Northwestern Federal District > Komi Republic > Nenets Autonomous Okrug > Timan-Pechora Basin (0.99)
- (31 more...)
About 3 years have elapsed since the previous World Petroleum Congress. Those years have seen dramatic changes in the Russian oil industry. Our trade has got into a deep crisis. Sufice it is to note that the production of oil and gas condensate dropped from 462 mln tons in 1991 to 351 mln tons in 1993. This has been caused by a lot of reasons, beginning with geological and down to economic. The said period is characterised by the quantitative change in the state of the raw material base. At present, over 60% of the current reserves are under development and their depletion has reached 55%. The highest depletion is characteristic for major fields: it is 70% for Samotlor, 60% for Fyodorovskoye, 87% for Romashkino and 80% for Arlanskoye fields. Correspondingly, the water cut in the wells is also high. On the average it is about 60% in Western Siberia and 70% in the Volga-Urals region. Practically the entire stock of wells has been mechanised. The production rate of old wells decreased from 10 tonsfday in 1991 to 8.3 tonsfday in 1993, and that of the new wells-from 14.2 tonsfday to 12 tons/day, respectively. The said factors have resulted in increased demand for material and financial resources needed to develop the industry. It was at%me that major economic and political Russia. Economic ties between companies were disrupted. Most harmful effect on the industry was produced by the disruption of economic relations with Azerbaidgan and the Ukraine, who, in a way, were monopolists in the manufacture of oilfield equipment and oil tubular goods. Negative impact was produced by the pricing and taxation policy that, in the course of economic reforms, brought about a deficit of financial resources for the development of the industry. The problem was aggravated by the general non-payment crisis in the Russian economy. changes too '\k place in the former USSR and in All these factors resulted in a sharp drop of investment. Thus the meterage of drilling decreased from 29.1 mln m to 19.5 mln m over the period of 1991- 1993, and more specifically, from 27.6 rnln to 18.3 rnln m in production drilling and from 1.5 mln m to 1.3 mln m in exploratory drilling. The decline in drilling resulted in a decline of the number of newly commissioned wells from 10251 wells to 7575 wells. The crisis in the Russian economy could not but have a negative impact on the geological and exploration industry. Over the period of 1988 to 1992 alone the meterage of exploratory drilling for oil and gas decreased 2 times, namely from 6.5 mln m to 3.1 mln m. However beginning from last year this trend is getting on the reverse, especially in Western Siberia, which will allow to get a major share of oil reserves in the near future. The major oil production areas are, and have always been, Western Siberia, Volga-Urals region and the northern edge of the
- Asia > Russia (1.00)
- Europe > Russia > Volga Federal District > Bashkortostan (0.24)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > P’nyang Field (0.98)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Elk-Antelope Field (0.98)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Angore Field (0.98)
- (9 more...)
Abstract. With the growing gas demand for the coming years and the rising cost of labour and construction, emphasis has been put on improving the economics of gas projects by reducing the Capital and Operations Expenditure. The result of the considerable on going effort has paved the way for breakthroughs in many different areas of the Processing of Cias. Innovation has enabled the producers to reduce significantly the processing on site. The awareness of the cost of utilities has brought more efficient designs of processes leading also to savings on Capital. This paper reviews some of the areas in which progress has been made and where more is expected to come. This ranges from subsea well head technology, two phase flows, unmanned production, to Research and Development on new products, chemicals and metallurgy. The industry can face the challenge of the coming years with such improvements over the past technology. 1. INTRODUCTION The perspectives of the world primary energy demand for the years 1990 and 2005 (Fig. 1) indicate that the share of Natural Gas is constantly increasing. This is all the more true for the European gas demand which is expected to increase by 50% by 2010. Analysing both the current situation and the perspective world wide of the gas industry for the next decade, there appears a consistent trend of simultaneous increase in reserves, production and world consumption. As has been highlighted in other sessions of this conference, the Natural Gas Industry will face a serious challenge to meet the spiralling cost of supply in a particularly difficult economic context. Fortu- 1990 2005 Source = EEC Fig. 1. Primary energy world demand. nately for the Natural Gas Industry one of its assets is its ability to challenge constantly its limitations by a continuous effort in Research and Development. In this respect, capital costs have fallen by 25% since 1986 when the drop in oil prices initiated a fundamental reappraisal of everything that was being spent. This reduction has been made possible thanks to a considerable effort of the industry in Research and Development (R&D) to meet the challenges. It is estimated' that a further reduction of 30% in Capex and 50% in Opex could be achieved within the next 20 years. A few years ago, innovation meant improvement of know-how to produce more difficult fields whereas it now means improvement of the latter to produce at a lesser cost. The main parameters affecting cost reduction in projects are the following:–A good project definition –Extended use of satellite developments –Process minimization –Reduction of manning A good project definition. Since pre-project studies only account for a very small amount (circa 0.5%) of the total project
- Asia (0.94)
- Europe > United Kingdom > North Sea (0.69)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.31)
- Europe > United Kingdom > North Sea > Southern North Sea > Southern Gas Basin > Silver Pit Basin > Caister Murdoch System (CMS) > Block 44/23a > Caister Field > Westphalian Formation (0.99)
- Europe > United Kingdom > North Sea > Southern North Sea > Southern Gas Basin > Silver Pit Basin > Caister Murdoch System (CMS) > Block 44/22a > Murdoch Field > Westphalian Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Alwyn Area > Block 3/9 > Alwyn Area > Alwyn North Field (0.99)
- (7 more...)
Abstract. The development of marginal fields with short(er) life expectancy opens the way for Contractor owned and operated mobile drilling and production systems. The accelerated water injection project at Ekofisk for injection of 320000 barrels per day of treated seawater based on Contractor owned equipment was designed, built and installed in the field in just 7 months. Prior to presenting my paper, most of which was written quite sometime ago, allow me to update you on some of the more recent development trends in the North Sea: Offshore exploration activities have both slowed considerably down and has shifted from having its main focus on drilling activities to greater use of 3D seismics. New finds are still being made, but they are generally becoming both smaller and more complex. Both typical trends in mature oil and gas provinces. The more prevailing and continuing low oil price, high cost and high taxes make it difficult for the industry to make ends meet.-And create great opportunities for the Contracting Community. Governments and the industry in the U.K. as well as in Norway see this and have taken forceful initiatives with the aim of getting the costs down,-the factor that the industry can influence. The CRINE initiative in the U.K. and the Forum for Operation and Development in Norway both conclude that important cost savings are possible. The U.K. authorities have greatly assisted the process by introducing important taxation incentives for new marginal developments. Their colleagues in Norway seem to hope that the effects of the cost cutting together with some changes to the administrative procedures are enough. I think they are wrong. The Norwegian industry needs not only cost cutting, but more flexibility introduced to rules and regulations as well as special tax incentives for things to move ahead. Technology is probably the one single most important factor for the future of marginal fields but how we go about our business is important too. My paper deals with one aspect of a development of an offshore field-the method or the project's organisation and execution. INTRODUCTION The lifecycle of an oil field may be structured in three main phases :exploration development and production. The development phase starts at approval of the Plan for Development and Operation (PDO) and extends up to the day of first oil, at which the production phase starts. The oil companies use a number of different contractors to achieve objectives set throughout all phases of an oilfield's lifecycle. There are two main categories of contractors; on one hand the ones that mainly provide and deliver systems and equipment, on the other hand the ones that mainly provide services. In this picture Smedvig represents the latter. As a marine contractor our main line
- Europe > Norway (1.00)
- Europe > United Kingdom (0.75)
- North America > United States > Texas > Kleberg County (0.24)
- North America > United States > Texas > Chambers County (0.24)
Abstract. The profitability of offshore marginal developments is no longer the simple sum of the optimization of single disciplines, it is the result of a complex combination and integration of human resources, advanced techniques for P.M., design, construction and installation, with the eyes already on the most efficient management of the field during its operational life. Accordingly, the paper illustrates the approach followed by AGIP for the integrated development of several marginai gas fields in the Northern Adriatic, with special emphasis on:–modularization and standardization; –integration of safety, environmental protection and maintainability requirements from the very early stages of - contract strategy, in order to have a beneficial 'scale effect'; –early thorough investigation of areas for improvement (i.e. design, installation, field management); –continuous economical reanalysis as a support to P.M., for planning and control. The final picture summarizes the actual factors that can lead today to an optimization of the cost-benefit ratio in a broad variety of offshore fields development. feasibility and design; 1. INTRODUCTION According to a widespread experience, competitiveness in today's petroleum arena largely depends on the capability to respond in flexible, integrated and real time terms to the wide spectrum of problems arising in a complex, interdisciplinary market. In this light, competitiveness today is moreover affected by a number of negative factors:–generally stable consumption of oil in Western Countries, if not subject to reduction (due to alternate sources, industrial recession, etc.) –decreasing profits for the major oil companies, taken as a whole' –reduction of the net margin available, due to a generally increased tax pressure –greater marginality for the vast majority of developments that could be undertaken. On the gas side, while for example Italian consumption has continued a stable growth by some 3% per year, today's respect for an improved quality of life imposes more stringent constraints on safety, environmental protection and legislation related issues. This is certainly of paramount importance in areas such as the Northern Adriatic Sea, where geographical structure and population density make this area sensitive to any disturbance of the environment. Based on the above premises, this paper summarizes one of AGIP's current experiences in developing a set of 15 new and marginal gas fields, allowing their exploitation by means of thorough integration of all project phases. It must be pointed out that one of the main characteristics of this project is the high number of new fields to be simultaneously developed, in an area
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 23/17a > Barbara Field > Forties Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 23/16d > Barbara Field > Forties Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 23/16c > Barbara Field > Forties Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 23/11 > Barbara Field > Forties Formation (0.99)
[21]3 The Infrastructure of Research and Development in China’s Petroleum Industry
Li, Tian-Xiang (China National Petroleum Corporation, China) | Zhai, Guang-Ming (Research Institute of Petroleum Exploration and Development, China) | Chen, Li-Dian (Research Institute of Petroleum Exploration and Development, China) | Li, Da-Dong (Research Institute of Petroleum Processing, China)
Abstract. While R&D is playing an important role in China's growing up to be one of the major oil producing countries, a relatively complete R&D system has been formed. The infrastructure of this system is built up by three levels of organization: Research Institutes directly under China National Petroleum Corporation (CNPC) and China Petrochemical Corporation (SINOPEC); R&D centers of oilfields, refineries and other enterprises; the labs jointly operated by CNPC or SINOPEC with Chinese Academy of Sciences and universities. National companies are the center of this system, so that important projects can be organized to meet this country's requirements. Various organizations including oilfields, refineries and designing institutes, etc., are organized in this system, therefore, research results can be successfully and quickly applied in practice. The joint-labs can provide petroleum R&D the benefit of academic and technical support from other professional areas. The successful experience of managing such a system is: central management, rigorous managerial rules and regulations as well as establishment of key labs as the core of cooperation. However, strengthening directed basic research and international cooperation is the assignment to be further emphasized. 1. INTRODUCTION As a developing country, the early stage of the development of China's petroleum industry started under poor economic condition and unfavorable social environment. It was also predicted that China had a lack of petroleum reserves according to the geology theory of marine sedimentation. Through more than 50 years of constant striving effort, China's petroleum industry has significantly grown up. The inland oil and gas production has reached a capacity of 140 Mt/y and 15 Gm3/y respectively. The offshore oil production will be over 10 Mt/y in the near future. Total crude output ranks China fifth in the world. Last year, over 8000 wells were drilled and thermal recovery of heavy oil reached 10 Mt, both are the third place in the world. Right now, 1000 rigs and 270 seismic crews are working actively. More than 30 large oil production bases, each composed of several oilfields and 12 natural gas fields are in production. In addition, prospective reservoirs have been found at Tarim and Turfan-Hami basins, on shore areas of Northeast, Middle, North, East and South China as well as coastal continental shell, beach-shallow sea and paralic zones. Therefore, further exploration and development are promising. T
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.35)
- Government > Regional Government > Asia Government > China Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin (0.99)
- Asia > China > Tianjin > Bohai Basin > Huanghua Basin > Dagang Field (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Yian Formation (0.99)
- (2 more...)