CARBO Ceramics no http://www.carboceramics.ru/en/rss CARBO Ceramics http://www.carboceramics.ru/tresources/en/images/icons/tendenci34x15.gif http://www.carboceramics.ru/en/rss Copyright 2012 CARBO Ceramics Tendenci Association Software by Schipul - The Web Marketing Company en-us noemail@carboceramics.ru(Webmaster) carborussia noemail@carboceramics.ru Sun, 20 May 2012 21:43:38 GMT Articles http://www.carboceramics.ru/en/art/23/ <h2><img alt="" src="/attachments/wysiwyg/5/StrataGen-LOGO.gif" width="117" align="right" height="79" />Location: </h2> Barnett, Fayettville, Woodford and other gas shale formations<br> &nbsp;<br> <h2>Application/Technology Focus:</h2> Matrix permeabilities of these shales are extremely difficult to measure because they are so low, but various approaches to determine their value have yielded permeabilities on the order of 1-100 nanodarcies.<br> &nbsp;<br> <h2>Methodology:</h2> Both mapping and modeling have been used to investigate the important role of natural fractures in both the stimulation and production processes, the importance of conductivity in the developed fracture or fracture system and the critical influence of the matrix permeability.<br> &nbsp;<br> <h2>Client Value Results: </h2> Economic production can be achieved only with an enormous conductive surface area in contact with this matrix, either through existing natural fractures or the development of a fracture “network” during stimulation. Economic production would then also rely on the existence or development of sufficient conductivity within this network <br> &nbsp;<br> &nbsp;<br> <div>------------------------------------------------------------------------------------------</div> <div>&nbsp;</div> <h3>Authors</h3> <div>N.R. Warpinski, SPE, M.J. Mayerhofer, SPE, Pinnacle Technologies; M.C. Vincent, SPE, Carbo Ceramics; C.L. Cipolla, SPE, and E.P. Lolon, SPE, StrataGen Engineering</div> &nbsp;<br> <h3>Abstract</h3> Unconventional reservoirs such as gas shales and tight gas sands require technology-based solutions for optimum development. The successful exploitation of these reservoirs has relied on some combination of horizontal drilling, multi-stage completions, innovative fracturing, and fracture mapping to engineer economic completions. However, the requirements for economic production all hinge on the matrix permeability of these reservoirs, supplemented by the conductivity that can be generated in hydraulic fractures and network fracture systems. Simulations demonstrate that ultra-low shale permeabilities require an interconnected fracture network of moderate conductivity with a relatively small spacing between fractures to obtain reasonable recovery factors. Microseismic mapping demonstrates that such networks are achievable and the subsequent production from these reservoirs support both the modeling and the mapping. Tight gas sands, having orders of magnitude greater permeability than the gas shales, may be successfully depleted without inducing complex fracture networks, but other issues of damage and zonal coverage complicate recovery in these reservoirs. As with the shales, mapping has proved itself to be valuable in assessing the fracturing results.<br> &nbsp;<br> <h3>Introduction</h3> Unconventional reservoirs provide a significant fraction of gas production in North America and increasing amounts in some other regions of the world. Such reservoirs include tight gas sands, coalbed methane (CBM), and gas shales; in 2006 these reservoirs provided 43% of the US production of natural gas (Kuuskra1). Because of their limited permeability, which is foremost among many other complexities, some type of stimulation process (and/or dewatering in the case of CBM) is required to engender economic recovery from wells drilled into these formations.<br> &nbsp;<br> The focus of this paper is on gas shales, with particular emphasis on how these reservoirs perform relative to tight gas sands. The important role of natural fractures in both the stimulation and production processes, the importance of conductivity in the developed fracture or fracture system, and the critical influence of the matrix permeability are investigated using both mapping and modeling results.<br> &nbsp;<br> Gas shales, such as the Barnett, Fayettville, and Woodford in North America, are relatively recent plays, but gas production from shales has occurred since the early 1900’s from the Devonian shales of eastern North America and more recently from the Antrim shale and others. These shales2 typically contain a relatively high total organic content (e.g., the Barnett has a total organic content of 4-5%) and are apparently the source rock as well as the reservoir. The gas is stored in the limited pore space of these rocks (a few per cent, including both matrix and natural fractures) and a sizable fraction of the gas in place may be adsorbed on the organic material. Matrix permeabilities of these shales are extremely difficult to measure because they are so low, but various approaches to determine their value have yielded permeabilities on the order of 1-100 nanodarcies. Clearly, economic production cannot be achieved without an enormous conductive surface area in contact with this matrix, either through existing natural fractures or the development of a fracture “network” during stimulation. Economic production would then also rely on the existence or development of sufficient conductivity within this network.<br> &nbsp;<br> <div><img alt="" src="/attachments/wysiwyg/5/NewsIcon.gif" width="13" height="14" /> Download SPE Paper <a href="http://www.onepetro.org/mslib/app/Preview.do?paperNumber=SPE-114173-MS&amp;societyCode=SPE" target="_blank">114173</a> </div> <div><br> </div> <div>&nbsp;<br> © Copyright 2008. Society of Petroleum Engineers <br> </div> <br><br>9-Nov-08 6:00 PM Stimulating Unconventional Reservoirs: Maximizing Network Growth While Optimizing Fracture Conductivity - SPE 114173 Location: Barnett, Fayettville, Woodford and other gas shale formations Application/Technology Focus: Matrix permeabilities of these shales are extremely difficult to measure because they are so low, but various approaches to determine their value have yielded permeabilities on the order of 1-100 nanodarcies. Methodology: Both mapping and modeling have been used to investigate the important role of natural fractures in both the stimulation and production processes, the importance of conductivity in the developed fracture or fracture system and the critical influence of the matrix permeability. Client Value Results: Economic production can be achieved only with an enormous conductive surface area in contact with this matrix, either through existing natural fractures or the development of a fracture “network” during stimulation. Economic production would then also rely on the existence or development of sufficient conductivity within this network ------------------------------------------------------------------------------------------ Authors N.R. Warpinski, SPE, M.J. Mayerhofer, SPE, Pinnacle Technologies; M.C. Vincent, SPE, Carbo Ceramics; C.L. Cipolla, SPE, and E.P. Lolon, SPE, StrataGen Engineering Abstract Unconventional reservoirs such as gas shales and tight gas sands require technology-based solutions for optimum development. The successful exploitation of these reservoirs has relied on some combination of horizontal drilling, multi-stage completions, innovative fracturing, and fracture mapping to engineer economic completions. However, the requirements for economic production all hinge on the matrix permeability of these reservoirs, supplemented by the conductivity that can be generated in hydraulic fractures and network fracture systems. Simulations demonstrate that ultra-low shale permeabilities require an interconnected fracture network of moderate conductivity with a relatively small spacing between fractures to obtain reasonable recovery factors. Microseismic mapping demonstrates that such networks are achievable and the subsequent production from these reservoirs support both the modeling and the mapping. Tight gas sands, having orders of magnitude greater permeability than the gas shales, may be successfully depleted without inducing complex fracture networks, but other issues of damage and zonal coverage complicate recovery in these reservoirs. As with the shales, mapping has proved itself to be valuable in assessing the fracturing results. Introduction Unconventional reservoirs provide a significant fraction of gas production in North America and increasing amounts in some other regions of the world. Such reservoirs include tight gas sands, coalbed methane (CBM), and gas shales; in 2006 these reservoirs provided 43% of the US production of natural gas (Kuuskra1). Because of their limited permeability, which is foremost among many other complexities, some type of stimulation process (and/or dewatering in the case of CBM) is required to engender economic recovery from wells drilled into these formations. The focus of this paper is on gas shales, with particular emphasis on how these reservoirs perform relative to tight gas sands. The important role of natural fractures in both the stimulation and production processes, the importance of conductivity in the developed fracture or fracture system, and the critical influence of the matrix permeability are investigated using both mapping and modeling results. Gas shales, such as the Barnett, Fayettville, and Woodford in North America, are relatively recent plays, but gas production from shales has occurred since the early 1900’s from the Devonian shales of eastern North America and more recently from the Antrim shale and others. These shales2 typically contain a relatively high total organic content (e.g., the Barnett has a total organic content of 4-5%) and are apparently the source rock as well as the reservoir. The gas is stored in the limited pore space of these rocks (a few per cent, including both matrix and natural fractures) and a sizable fraction of the gas in place may be adsorbed on the organic material. Matrix permeabilities of these shales are extremely difficult to measure because they are so low, but various approaches to determine their value have yielded permeabilities on the order of 1-100 nanodarcies. Clearly, economic production cannot be achieved without an enormous conductive surface area in contact with this matrix, either through existing natural fractures or the development of a fracture “network” during stimulation. Economic production would then also rely on the existence or development of sufficient conductivity within this network. Download SPE Paper 114173 © Copyright 2008. Society of Petroleum Engineers no http://www.carboceramics.ru/en/art/23/ StrataGen Engineering - noemail@carboceramics.ru Mon, 10 Nov 2008 00:00:00 GMT Articles http://www.carboceramics.ru/en/art/16/ <h2><img alt="" src="/attachments/wysiwyg/5/C_Ceramics_LOGO.gif" align="right" border="0" height="51" width="118" />Location: </h2> Northwest India (Rajasthan,) Raageshwari deep gas field<br> &nbsp;<br> <h2>Application/Technology Focus:</h2> Natural gas from a deep, tight formation was needed in order to heat and process waxy oil from a massive oil field discovered nearby.<br> &nbsp;<br> <h2>Methodology:</h2> Core testing, fluids compatibility testing, pre-fracture diagnostic injections, fracture simulation and post-stimulation production evaluation.<br> &nbsp;<br> <h2>Client Value Results </h2> Three deep gas wells in formations of varying permeability were stimulated successfully. Post-fracture well testing showed initial production rates agreeing with what was expected based on reservoir simulation. This important result supports the proposition that unconventional gas resources in Asian countries can be attractive when applying stimulation techniques perfected in other areas (i.e. North America).<br> &nbsp;<br> &nbsp;<br> ------------------------------------------------------------------------------------------<br> <div>&nbsp;</div> <h3>Authors</h3> <div><strong style="margin-top: 0px; margin-right: 0px; margin-bottom: 0px; margin-left: 0px; padding-top: 0px; padding-right: 0px; padding-bottom: 0px; padding-left: 0px; "></strong>Josef Shaoul, Pinnacle Technologies; Michael Ross, Cairn Energy PLC; Winston Spitzer, Pinnacle Technologies; Stuart Wheaton, RISC UK Ltd.; Paul Mayland, BG Canada; and Arvinder Paul Singh, Cairn Energy PLC.&nbsp;</div> &nbsp;<br> <h3>Abstract</h3> Tight gas fracturing was pioneered in North America in the 1970’s and 1980’s, and also has a relatively long history in Germany. In the rest of the world, however, massive fracturing for production from tight gas formations (i.e. k &lt; 0.1 mD) has been very rare, due mainly to poor economics, rather than lack of opportunities. A massive oil field was recently discovered in Rajasthan (northwest India). The field development would require significant amounts of natural gas for heating and processing of the waxy oil to be produced. The most economical solution to provide sufficient gas in this remote desert location was to produce it from a deeper formation discovered in the same area. The majority of the gas is contained in a volcanic section of basalts and felsics. A fracturing campaign was performed in 2006 on three deep gas wells to evaluate the post-stimulation production increase from a number of different horizons, with base formation permeability varying from 0.005 to 0.15 mD. <br> &nbsp;<br> A comprehensive program of core testing, fluids compatibility testing and pre-fracture diagnostic injections was performed. Fracture stimulation treatments were performed in three different sections of this very thick gas-bearing formation (&gt; 400 m gross height). The formations ranged from the highest permeability (0.15 mD) Fatehgarh sandstones, to a lower permeability Felsic section (0.05 mD) and the lowest permeability volcanic rock (0.005 mD). All three types of rock were stimulated successfully and post-fracture well testing showed initial production rates agreeing with what was expected based on reservoir simulation. This important result supports the proposition that unconventional gas resources in Asian countries can be attractive when applying stimulation techniques perfected in other areas (i.e. North America).<br> &nbsp;<br> <h3>Introduction
</h3> <div> The Raageshwari Deep gas field was discovered by RJ-E-1 (Raageshwari-1) in 2003. It was the second well drilled on the Central Basin High (CBH), a 40km-long composite feature of elevated N-S-oriented fault terraces, arranged in echelon within the Southern Barmer Basin of Rajasthan (Figure 1). The Central Basin High (CBH) structure is divided into many major horst blocks, of which Raageshwari is the shallowest. Raageshwari Deep is a tight lean gas condensate field and is contained in an arrowhead-shaped horst block formed at the confluence of three fault trends and contains 4 reservoir bodies (Fatehgarh, Basalt, Felsic and Sub-Felsic).</div> <div>&nbsp;</div> <blockquote> <div><img alt="" src="/attachments/wysiwyg/5/NewsIcon.gif" height="14" width="13" /> Download SPE Paper <a target="_blank" href="http://www.onepetro.org/mslib/app/Preview.do?paperNumber=SPE-107337-MS&amp;societyCode=SPE">107337</a></div> <div><br> </div> </blockquote> &nbsp;&nbsp;<br> ©Copyright 2007. Society of Petroleum Engineers <br><br>9-Nov-07 4:15 PM Massive Hydraulic Fracturing Unlocks Deep Tight Gas Reserves in India (SPE 107337) Location: Northwest India (Rajasthan,) Raageshwari deep gas field Application/Technology Focus: Natural gas from a deep, tight formation was needed in order to heat and process waxy oil from a massive oil field discovered nearby. Methodology: Core testing, fluids compatibility testing, pre-fracture diagnostic injections, fracture simulation and post-stimulation production evaluation. Client Value Results Three deep gas wells in formations of varying permeability were stimulated successfully. Post-fracture well testing showed initial production rates agreeing with what was expected based on reservoir simulation. This important result supports the proposition that unconventional gas resources in Asian countries can be attractive when applying stimulation techniques perfected in other areas (i.e. North America). ------------------------------------------------------------------------------------------ Authors Josef Shaoul, Pinnacle Technologies; Michael Ross, Cairn Energy PLC; Winston Spitzer, Pinnacle Technologies; Stuart Wheaton, RISC UK Ltd.; Paul Mayland, BG Canada; and Arvinder Paul Singh, Cairn Energy PLC. Abstract Tight gas fracturing was pioneered in North America in the 1970’s and 1980’s, and also has a relatively long history in Germany. In the rest of the world, however, massive fracturing for production from tight gas formations (i.e. k &lt; 0.1 mD) has been very rare, due mainly to poor economics, rather than lack of opportunities. A massive oil field was recently discovered in Rajasthan (northwest India). The field development would require significant amounts of natural gas for heating and processing of the waxy oil to be produced. The most economical solution to provide sufficient gas in this remote desert location was to produce it from a deeper formation discovered in the same area. The majority of the gas is contained in a volcanic section of basalts and felsics. A fracturing campaign was performed in 2006 on three deep gas wells to evaluate the post-stimulation production increase from a number of different horizons, with base formation permeability varying from 0.005 to 0.15 mD. A comprehensive program of core testing, fluids compatibility testing and pre-fracture diagnostic injections was performed. Fracture stimulation treatments were performed in three different sections of this very thick gas-bearing formation (&gt; 400 m gross height). The formations ranged from the highest permeability (0.15 mD) Fatehgarh sandstones, to a lower permeability Felsic section (0.05 mD) and the lowest permeability volcanic rock (0.005 mD). All three types of rock were stimulated successfully and post-fracture well testing showed initial production rates agreeing with what was expected based on reservoir simulation. This important result supports the proposition that unconventional gas resources in Asian countries can be attractive when applying stimulation techniques perfected in other areas (i.e. North America). Introduction
 The Raageshwari Deep gas field was discovered by RJ-E-1 (Raageshwari-1) in 2003. It was the second well drilled on the Central Basin High (CBH), a 40km-long composite feature of elevated N-S-oriented fault terraces, arranged in echelon within the Southern Barmer Basin of Rajasthan (Figure 1). The Central Basin High (CBH) structure is divided into many major horst blocks, of which Raageshwari is the shallowest. Raageshwari Deep is a tight lean gas condensate field and is contained in an arrowhead-shaped horst block formed at the confluence of three fault trends and contains 4 reservoir bodies (Fatehgarh, Basalt, Felsic and Sub-Felsic). Download SPE Paper 107337 ©Copyright 2007. Society of Petroleum Engineers no http://www.carboceramics.ru/en/art/16/ CARBO Ceramics - noemail@carboceramics.ru Fri, 09 Nov 2007 22:15:00 GMT Articles http://www.carboceramics.ru/en/art/28/ <h2><img alt="" src="/attachments/wysiwyg/5/C_Ceramics_LOGO.gif" align="right" height="51" width="118" />Location: </h2> Southwest Texas, Mesquite Field, Escondido Formation, polymer emulsion fluid, refracture<br> &nbsp;<br> <h2>Application/Technology Focus:</h2> Initial fracs using small sand volumes in low viscosity fluid doubled production, but rapidly declined to pre-frac rate.<br> &nbsp;<br> <h2>Methodology:</h2> Five wells were selected for refracturing with higher viscosity fluids, increased proppant concentration, larger proppant diameter and greater proppant mass.<br> &nbsp;<br> <h2>Client Value Results: </h2> <div>Average production increase due to the refracs was 620%. Evaluation of pre and post frac flow rates and decline curves indicates an approximate doubling of recoverable reserves.</div> <div><br> </div> <div> </div> <div>&nbsp;</div> <div>------------------------------------------------------------------------------------------<br> <div>&nbsp;</div> <div> <h3>Abstract</h3> This paper presents the results of an effort to improve productivity of the low permeability Escondido Formation in Webb County, Texas, by the use of an improved hydraulic fracture design. <br> <br> A fracture treatment using the polymer emulsion fluid system was designed to provide sufficient propped fracture length and area to maintain long-term productivity of the wells. The polymer emulsion fluid was selected for its good proppant transport and low fluid loss properties. Five previously drilled and stimulated wells and three new wells were fractured with the polymer emulsion treatments. Evaluation of pre and post frac flow rates and decline curves indicates an approximate doubling of recoverable reserves. <br> &nbsp;<br> <h3>Introduction</h3> The Mesquite Field is in Webb County in Southwestern Texas about 15 miles north of the town of Laredo. Drilling was started in the mid 1970s. The Escondido production occurs within a broad stratigraphic trap. Production from the wells on initial completion without stimulation is considered non-commercial. The Escondido is recognized to have significant potential for producing natural gas.<br> &nbsp;<br> The wells in the Mesquite Field are located on approximately a 320 acre (127.5 hectare) spacing. However, well performance indicates that 160 acre (64.75 hectare) spacing may be more suitable for estimating reserves. Based on the 160 acre (64.75 hectare) spacing the wells contain an average estimated gas in place quantity of 1500 MMcf (4.25 E+07 m3).<br> &nbsp;<br> It is evident that even though a good amount of gas is present, the production rate needs to be improved to make the wells commercial. Previous attempts to increase production with "conventional" gelled water fracs were partially successful, but rapid declines in production indicated that an improved stimulation treatment was necessary to maintain long-tern productivity.<br> &nbsp;<br> <div>&nbsp;<img alt="" src="/attachments/wysiwyg/5/NewsIcon.gif" height="14" width="13" /> Download Paper <a target="_blank" href="http://www.onepetro.org/mslib/app/Preview.do?paperNumber=00007912&amp;societyCode=SPE">7912</a> </div> <div>&nbsp;</div> <div><strong>Authors</strong>: D.P. Kundert, Halliburton Services; D.E. Smink, Consultant<br> &nbsp;<br> <strong>Paper</strong>: 7912<br> &nbsp;<br> © Copyright 1979, American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Kundert, D.P., Halliburton Services; Smink, D.E., Consultant</div> </div> </div> <br><br>9-Nov-79 7:00 PM Improved Stimulation of the Escondido Sandstone (CARBO-authored) Location: Southwest Texas, Mesquite Field, Escondido Formation, polymer emulsion fluid, refracture Application/Technology Focus: Initial fracs using small sand volumes in low viscosity fluid doubled production, but rapidly declined to pre-frac rate. Methodology: Five wells were selected for refracturing with higher viscosity fluids, increased proppant concentration, larger proppant diameter and greater proppant mass. Client Value Results: Average production increase due to the refracs was 620%. Evaluation of pre and post frac flow rates and decline curves indicates an approximate doubling of recoverable reserves. ------------------------------------------------------------------------------------------ Abstract This paper presents the results of an effort to improve productivity of the low permeability Escondido Formation in Webb County, Texas, by the use of an improved hydraulic fracture design. A fracture treatment using the polymer emulsion fluid system was designed to provide sufficient propped fracture length and area to maintain long-term productivity of the wells. The polymer emulsion fluid was selected for its good proppant transport and low fluid loss properties. Five previously drilled and stimulated wells and three new wells were fractured with the polymer emulsion treatments. Evaluation of pre and post frac flow rates and decline curves indicates an approximate doubling of recoverable reserves. Introduction The Mesquite Field is in Webb County in Southwestern Texas about 15 miles north of the town of Laredo. Drilling was started in the mid 1970s. The Escondido production occurs within a broad stratigraphic trap. Production from the wells on initial completion without stimulation is considered non-commercial. The Escondido is recognized to have significant potential for producing natural gas. The wells in the Mesquite Field are located on approximately a 320 acre (127.5 hectare) spacing. However, well performance indicates that 160 acre (64.75 hectare) spacing may be more suitable for estimating reserves. Based on the 160 acre (64.75 hectare) spacing the wells contain an average estimated gas in place quantity of 1500 MMcf (4.25 E+07 m3). It is evident that even though a good amount of gas is present, the production rate needs to be improved to make the wells commercial. Previous attempts to increase production with "conventional" gelled water fracs were partially successful, but rapid declines in production indicated that an improved stimulation treatment was necessary to maintain long-tern productivity. Download Paper 7912 Authors: D.P. Kundert, Halliburton Services; D.E. Smink, Consultant Paper: 7912 © Copyright 1979, American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Kundert, D.P., Halliburton Services; Smink, D.E., Consultant no http://www.carboceramics.ru/en/art/28/ CARBO Ceramics - noemail@carboceramics.ru Sat, 10 Nov 1979 01:00:00 GMT Release http://www.carboceramics.ru/en/rel/12/ <p><strong>HOUSTON (June 28, 2010)</strong> – CARBO announced today the introduction of CARBONRT™, an innovative, environmentally responsible development in proppant placement. This technology incorporates a taggant that allows down hole, near wellbore detection of ceramic proppant. CARBONRT assists in determining fracture propagation and geometry in a manner that is designed to optimize stimulation effectiveness and maximize productive capacity.</p> <p>With non-radioactive CARBONRT, there is no half-life deterioration of the detectable properties.&nbsp;&nbsp; The proppant is engineered for extended identification, giving operators the flexibility of conducting post-frac logging months or years after fracturing.</p> <p>The proprietary tracer can be added to any ceramic proppant in CARBO’s extensive product line. It is uniformly distributed through each grain of proppant, assuring consistent distribution of the traceable marker throughout the fracture zone. </p> <p>“CARBONRT is a unique product that offers the E&amp;P industry a traceable proppant without the half-life and potential environmental hazards involved with radioactive tracers,” said Gary Kolstad, CARBO’s President and Chief Executive Officer.&nbsp; “This provides flexibility to conduct proppant detection analysis with standard logging tools for an indefinite period of time.” </p> <div>&nbsp;</div> <div><strong>Company Information:<br></strong>CARBO is the world's largest supplier of ceramic proppant for fracturing oil and gas wells; provider of the world's most popular fracture simulation software; and a provider of fracture design and consulting services. The company also provides a broad range of technologies for spill prevention, containment and countermeasures, along with geotechnical monitoring. <br><br>###</div> <div><br><strong>FOR MORE INFORMATION:<br></strong>Steve Bell<br>Director of Marketing Communications<br>281-921-6400</div> <div><a href="mailto:steve.bell@carboceramics.com">steve.bell@carboceramics.com</a></div> http://www.carboceramics.ru/en/rel/12/ noemail@carboceramics.ru Mon, 28 Jun 2010 21:00:00 GMT Release http://www.carboceramics.ru/en/rel/8/ <div>Everything You’ve Always Wanted to Know about Hydraulic Fracturing Proppant... But Were Afraid to Ask!</div> <div>Click here to register: <a href="http://www.spegcs.org/en/cev/1667">http://www.spegcs.org/en/cev/1667</a></div> http://www.carboceramics.ru/en/rel/8/ noemail@carboceramics.ru Wed, 27 Jan 2010 17:00:00 GMT Release http://www.carboceramics.ru/en/rel/5/ HOUSTON (November 17, 2009) -- CARBO Ceramics Inc. (NYSE: CRR) today announced the company's board of directors (Board) elected Sigmund L. Cornelius as an additional member of the Board. Mr. Cornelius is the Senior Vice President, Finance and Chief Financial Officer of ConocoPhillips and has over 25 years of experience in the oil and natural gas industry. Mr. Cornelius has also been appointed to the Compensation, Audit and Nominating and Corporate Governance Committees of the Board. We are pleased with the addition of Sig to our Board and look forward to gaining the value of his experience in the energy industry, said Gary Kolstad, President and CEO. He brings a wealth of expertise in global operations and has a deep understanding of finance and accounting principles, concluded Mr. Kolstad. CARBO is the world's largest supplier of ceramic proppant, the provider of the world's most popular fracture simulation software, and provides leading fracture design and consulting... http://www.carboceramics.ru/en/rel/5/ noemail@carboceramics.ru Tue, 17 Nov 2009 16:00:00 GMT Release http://www.carboceramics.ru/en/rel/6/ Houston, Texas (October 2, 2009) -- CARBO Ceramics Inc. (CARBO) announced today that it has acquired through a wholly owned subsidiary the assets of BBL Falcon Industries, Ltd., a leading supplier of spill prevention and containment systems for the oil and gas industry. President and CEO Gary Kolstad commented, Falcon is an excellent addition to CARBO's current product and service offerings. We are excited about adding another growing business to CARBO, and are pleased that we will be selling Falcon's products and services to our existing client base of E&P and oilfield services companies. Falcon uses proprietary technology to provide value-added solutions that are designed to enable our clients to extend the life of their storage assets, reduce the potential for hydrocarbon spills and provide secure containment of stored materials. We believe these issues remain important as the oil and gas industry continues to increase its focus on environmental responsibility and compliance... http://www.carboceramics.ru/en/rel/6/ noemail@carboceramics.ru Fri, 02 Oct 2009 15:00:00 GMT Content Managers http://www.carboceramics.ru/stratagen-team/ Сотрудники StrataGen доказали, что для них нет ничего невозможного. Консультанты StrataGen предоставляют услуги мирового класса, которые помогают нашим клиентам добиваться... http://www.carboceramics.ru/stratagen-team/ Thu, 01 Mar 2012 10:03:18 GMT Content Managers http://www.carboceramics.ru/contact-fracproPT/ <div> &nbsp;</div> <div> &nbsp;</div> <div> <strong>Офис по продажам Fracpro и StimPT и технической поддержке пользователей:</strong><br> Россия 115114, Москва, ул. Дербеневская, д. 1<br> Бизнес Парк &quot;Дербеневский&quot;, корпус № 1, подъезд № 23<br> Тел.: +7 (495) 7814820<br> Факс: +7 (495) 7812528</div> http://www.carboceramics.ru/contact-fracproPT/ Thu, 16 Feb 2012 12:11:50 GMT Content Managers http://www.carboceramics.ru/fracpropt-software/ Fracpro: Выбор оптимального решения Наиболее распространенное в мире программное обеспечение для моделирования ГРП предлагает непревзойденные возможности,... http://www.carboceramics.ru/fracpropt-software/ Thu, 16 Feb 2012 12:07:30 GMT Content Managers http://www.carboceramics.ru/en/cms/1599/ <div> <h2> Быстрые ссылки</h2> <ul> <li> <a href="/ceramic-proppant/">Пропанты CARBO Ceramics</a></li> <li> <a href="/fracture-engineering/">Проектирование ГРП</a></li> <li> <a href="/reservoir-engineering/">Разработка пласта</a></li> <li> <a href="/fracpropt/">Fracpro</a></li> </ul> </div> http://www.carboceramics.ru/en/cms/1599/ Thu, 16 Feb 2012 12:06:59 GMT Content Managers http://www.carboceramics.ru/en/cms/173/ CARBO является общепризнанным лидером в разработке инновационных продуктов и услуг, приносящих прибыль клиентам компании. В нефтегазовой сфере CARBO Ceramics является... http://www.carboceramics.ru/en/cms/173/ Thu, 16 Feb 2012 12:06:47 GMT Content Managers http://www.carboceramics.ru/contacts-for-carbo-ceramics/ <div> <br> <strong>Офис по продажам и поддержке клиентов:</strong><br> Россия 115114, Москва, ул. Дербеневская, д. 1<br> Бизнес Парк &quot;Дербеневский&quot;, корпус №1, подъезд №23<br> Тел.: +7 (495) 7814820<br> Факс: +7 (495) 7812528</div> <div> &nbsp;</div> <div> &nbsp;</div> <div> <strong>Завод по производству пропантов:</strong><br> Россия 456658, Челябинская область, Копейский городской округ, Еткульский тракт, 11<br> Тел.: +7 (351) 2472030<br> Факс: +7 (351) 2472035</div> <div> <iframe frameborder="0" height="800" marginheight="0" marginwidth="0" src="https://spreadsheets.google.com/spreadsheet/embeddedform?formkey=dGpWa0E3VWFWeGFTRldBS2REaExUSGc6MQ" width="760">Loading...</iframe></div> http://www.carboceramics.ru/contacts-for-carbo-ceramics/ Thu, 16 Feb 2012 11:58:56 GMT Content Managers http://www.carboceramics.ru/fracture-courses/ <div> <iframe src="https://docs.google.com/spreadsheet/embeddedform?formkey=dGU2ZF9JYUEtY2NhbS1RYVJ2TmcxVUE6MQ" width="760" height="1544" frameborder="0" marginheight="0" marginwidth="0">Loading...</iframe></div> http://www.carboceramics.ru/fracture-courses/ Thu, 12 Jan 2012 22:29:43 GMT Content Managers http://www.carboceramics.ru/contact-carbo <div> <div><iframe src="https://docs.google.com/spreadsheet/embeddedform?formkey=dG9fSmd5MW43UFk3cWpMTXVienRsQWc6MQ" width="760" height="925" frameborder="0" marginheight="0" marginwidth="0">Loading...</iframe> <div> <b><br> </b></div> </div> </div> http://www.carboceramics.ru/contact-carbo Thu, 12 Jan 2012 22:12:48 GMT Content Managers http://www.carboceramics.ru/contact-agi <div> <div> <iframe frameborder="0" height="925" marginheight="0" marginwidth="0" src="https://docs.google.com/spreadsheet/embeddedform?formkey=dGpxMTlQT0pweU84VlFzSlFkRzlvLWc6MQ" width="760">Loading...</iframe><font face="Arial, Helvetica, sans-serif"><b><br> </b></font></div> </div> http://www.carboceramics.ru/contact-agi Thu, 12 Jan 2012 21:59:44 GMT Content Managers http://www.carboceramics.ru/Contact-CARBO-Ceramics <div> <iframe src="https://docs.google.com/spreadsheet/embeddedform?formkey=dEpIV1diRkVaUndsN3Y3dzh5ZXJ4MFE6MQ" width="760" height="925" frameborder="0" marginheight="0" marginwidth="0">Loading...</iframe></div> http://www.carboceramics.ru/Contact-CARBO-Ceramics Thu, 12 Jan 2012 21:54:49 GMT Survey http://www.carboceramics.ru/en/sur/?1 Objectives: <p>Lorem ipsum dolor sit amet, consectetuer adipiscing elit, sed diem nonummynibh euismod tincidunt ut lacreet dolore magna aliguam erat volutpat. Ut wisis enim ad minim veniam, quis nostrud exerci tution ullamcorper suscipit lobortis nisl ut aliquip ex ea commodo consequat. Duis te feugifacilisi. </p> <p>Duis autem dolor in hendrerit in vulputate velit esse molestie consequat, vel illum dolore eu feugiat nulla facilisis at vero eros et accumsan et iusto odio dignissim qui blandit praesent luptatum zzril delenit au gue duis dolore te feugat nulla facilisi. </p> <p>Ut wisi enim ad minim veniam, quis nostrud exerci taion ullamcorper suscipit lobortis nisl ut aliquip ex en commodo consequat. Duis te feugifacilisi per suscipit lobortis nisl ut aliquip ex en commodo consequat.Lorem ipsum dolor sit amet, consectetuer adipiscing elit, sed diem nonummy nibh euismod tincidunt ut lacreet dolore magna aliguam erat volutpat. </p> <p>Ut wisis enim ad minim veniam, quis nostrud exerci<br><br>Release Date: 2-Apr-09 11:57 AM<br>Expiration Date: 2-Jul-09 11:57 AM<br><p>Lorem ipsum dolor sit amet, consectetuer adipiscing elit, sed diem nonummynibh euismod tincidunt ut lacreet dolore magna aliguam erat volutpat. Ut wisis enim ad minim veniam, quis nostrud exerci tution ullamcorper suscipit lobortis nisl ut aliquip ex ea commodo consequat. Duis te feugifacilisi. </p> <p>Duis autem dolor in hendrerit in vulputate velit esse molestie consequat, vel illum dolore eu feugiat nulla facilisis at vero eros et accumsan et iusto odio dignissim qui blandit praesent luptatum zzril delenit au gue duis dolore te feugat nulla facilisi. </p> <p>Ut wisi enim ad minim veniam, quis nostrud exerci taion ullamcorper suscipit lobortis nisl ut aliquip ex en commodo consequat. Duis te feugifacilisi per suscipit lobortis nisl ut aliquip ex en commodo consequat.Lorem ipsum dolor sit amet, consectetuer adipiscing elit, sed diem nonummy nibh euismod tincidunt ut lacreet dolore magna aliguam erat volutpat. </p> <p>Ut wisis enim ad minim veniam, quis nostrud exerci http://www.carboceramics.ru/en/sur/?1 noemail@carboceramics.ru Thu, 02 Apr 2009 16:57:58 GMT Courses http://www.carboceramics.ru/en/courses/view.asp?courseid=1
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