Oil and gas facilities最新文献

{"title":"A Critical Review of Alternative Desalination Technologies for Smart Waterflooding","authors":"S. Ayirala, A. Yousef","doi":"10.2118/179564-PA","DOIUrl":"https://doi.org/10.2118/179564-PA","url":null,"abstract":"The results of this review study show that there is no commercial technology yet available to selectively remove specific ions from seawater in one step and optimally meet the desired water-chemistry requirements of smart waterflooding. As a result, different conceptual process configurations involving selected combinations of chemical precipitation, conventional/emerging desalination, and produced-water-treatment technologies are proposed. These configurations represent both approximate and improved solutions to incorporate specific key ions into the smart water selectively, besides presenting the key opportunities to treat produced-water/ membrane reject water and provide ZLD capabilities in smartwaterflooding applications. The developed configurations can provide an attractive solution to capitalize on existing huge producedwater resources available in carbonate reservoirs to generate smart water and minimize wastewater disposal during fieldwide implementation of smart waterflood.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88908896","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pressure-Minimization Method for Prediction of Two-Phase-Flow Splitting","authors":"Ramin Dabirian, L. Thompson, R. Mohan, O. Shoham","doi":"10.2118/166197-PA","DOIUrl":"https://doi.org/10.2118/166197-PA","url":null,"abstract":"was developed to predict the splitting phenomena under these regimes. Shoham extended his flow-splitting work to a horizontal reduced tee with a smaller-diameter branch arm (Shoham et al. 1989). Hong (1978) studied two-phase-flow splitting for a branching tee, considering the effect of side-arm angle and flow regimes on gas and liquid splitting. Hong and Griston (1995) studied flow splitting of an air/water system and concluded that, as the air split ratio increased to greater than 2:1, the experimental data points deviated from a 50:50 split. Hong and Griston (1995) also studied the effects of some devices on flow splitting. They recommended that nozzles be inserted directly downstream of an impacting tee to increase the chance of equal splitting. Azzopardi et al. (1987) considered the effects of annular flow for splitting at the tee junction. Azzopardi et al. (1988) investigated the effect of churn flow in the tee junctions. The experimental results for churn flow were the same as those for annular flow; therefore, they concluded that the inletgasand liquid-flow rates do not affect flow splitting. Peake (1992) concluded theoretically that uneven two-phase-flow splitting occurs as a result of unequal vapor-flow splitting. Tshuva et al. (1999) studied two-phase-flow splitting in horizontal and inclined parallel pipes. Taitel et al. (2003) studied the splitting of gas and liquid for four parallel pipes with a common inlet and outlet manifold capable of inclining from 0 to 15°. For the horizontal case, they observed identical splitting for each looped pipe, while for the other inclination angles, they observed a stagnant flow in at least one pipe. Pustylnik et al. (2006) investigated flow splitting in the lines on the basis of stability analysis, and proposed a model that was able to predict the number of pipes filled with stagnant liquid. One of the more-recent investigations on flow splitting was conducted by Alvarez et al. (2010). Their study investigated two-phase-flow splitting for looped lines such as parallel and looped configurations, and they developed a mechanistic model capable of predicting split ratio and pressure drop across each looped line on the basis of equal gas/liquid ratio in each branch. The purpose of our study is to discover the manner in which two phases of gas and liquid are split on the basis of the minimum pressure drop.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85123756","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Applying Subsea Fluid-Processing Technologies for Deepwater Operations","authors":"Xingru Wu, F. Babatola, Leiyong Jiang, B. Tolbert, Junrong Liu","doi":"10.2118/181749-PA","DOIUrl":"https://doi.org/10.2118/181749-PA","url":null,"abstract":"sand and entrained solids are removed. This is followed by the separation of the gas and liquid components in the hydrocarbon stream at the existing temperature and pressure. The gas stream is then compressed, and the liquid stream is pumped to a processing facility onshore. If it is necessary, the liquid stream can be further separated into oil and water, and the gas can be reinjected into the reservoir or wellstream to recover more liquid oil. Chemical conditioning and active heating may be applied subsea before the processed fluids are pumped to the receiving facility (Abili et al. 2012). In this paper, we discuss the components of a subsea processing system with emphasis on pumps and separation equipment. Additionally, we will investigate offshore assets that currently apply subsea processing technologies to extract hydrocarbons to identify challenges facing the industry and opportunities for the future development of subsea fluid-conditioning technologies.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80863104","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of Plume-Cooling Technology To Solve a GTG Impingement Problem: A Case Study","authors":"J. Thompson, R. Crampton","doi":"10.2118/176309-PA","DOIUrl":"https://doi.org/10.2118/176309-PA","url":null,"abstract":"• Warming of air over the helipad, causing a sudden change in aircraft performance and possible loss of control • Direct exposure of workers to elevated air temperatures and dangerous concentrations of carbon dioxide (CO2) and carbon monoxide (CO) The level of risk for the preceding impacts depends on the type and power output of the engine. Gas-turbine engines are particularly prone to impingement problems because of their high exhaust temperatures (> 500°C) and large volumetric flow rates. The diameter of the exhaust uptake and its proximity to AOIs on the platform also play an important role in the probability and severity of impingement impacts. Thus, platform designs that have their gasturbine engines located centrally tend to put many areas of the platform at risk. Up to this point, the standard practice for reducing the risk associated with exhaust-plume impingement has been to locate the exhaust-duct exit as far away from sensitive areas as possible, or to extend the exhaust duct vertically upward until all the AOIs are below the duct exit (Fig. 1). Either of these two solutions, although effective, can result in long exhaust-duct runs with associated support structure, which adds weight to the platform. There is another solution to the plume-impingement problem, and that is the use of plume-cooling technology. Plume cooling has been used successfully on military ships for more than 40 years as a means of reducing the IR signature of the ship. A ship’s engine exhausts are the primary source of heat aboard, and thus any reduction in the temperature of visible metal or plume will reduce the detectibility of the ship in the IR band (Thompson et al. 1998). Another advantage of the use of plume cooling aboard a ship is that the temperature of mast-mounted sensors and communications equipment is lower in the event that the plume impinges upon them. An example of plume-cooling use on a military ship is the USS Makin Island (LHD-8), shown in Fig. 2. This ship class was originally powered by steam turbines, but the eighth ship was converted to gas-turbine propulsion, which greatly increased exhaust-gas temperatures, and thus required plume cooling to protect equipment on the ship’s two masts. At the time this paper was written, the authors were not aware of any plume coolers in service aboard existing offshore facilities. Currently, there are three new platform constructions that have plume coolers installed on their GTGs: Chevron Big Foot, ExxonMobil Hebron, and Statoil Gina Krog. An explanation for why plume coolers have not been used more frequently to solve impingement problems may be as simple as designers are not aware that the technology exists. Bringing the benefits of plume cooling to the attention of designers and operators is the primary purpose of this paper. Plume coolers are simple air/air ejectors that passively draw in cool, ambient air and mix it with the exhaust gases before they exit the device (Birk and Davis 1998). Fig. 3 illu","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87553653","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Safety for a Helicopter Load/Unload Operation on an Offshore Platform: Optimization From Several Viewpoints and the Psychological Aspects of the Marshaller","authors":"H. Yonebayashi, T. Collins","doi":"10.2118/174721-PA","DOIUrl":"https://doi.org/10.2118/174721-PA","url":null,"abstract":"Field and Logistics. The field is located offshore, approximately 200 km (108 nm) away from the nearest airport. Flight time is 1 hour and 5 minutes in still air by a twin-engine medium-sized helicopter with two blades that has a cruise speed of 100 knots. In the case of a four-blade twin-engine helicopter with a cruise speed of 125 knots, flight time is 52 minutes in still air. In the case of vessel transportation, it takes 1 day from the nearest port. The field has been developed with facilities consisting of a central complex with living quarters and surrounding unmanned platforms. All wells are tied-in platforms. Produced fluids are sent to the central complex through subsea flowlines. The central complex has both a helideck and large crane equipment, while the platforms have a helideck and simple human-powered hoist equipment only, without any crane equipment. Regular or ad hoc but prescheduled material transportation is performed by an offshore support vessel between the nearest port and the central complex, except urgent/emergency transportation. Once materials arrive at the complex, the method of transportation from the complex to the platform depends on the situation. If there are small materials that can be managed by human carrying or lifting with simple hoist equipment, then those materials are transported by supply boat. Heavier materials that cannot be lifted by human power are transported by helicopter. There are three types of platforms—one-leg, three-leg, and four-leg. The number of well slots and the size of the helideck increase with the number of legs on the platform.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73072308","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Savvy Separator Series: Introduction to CFD for Separator Design","authors":"A. Read","doi":"10.2118/0616-0002-OGF","DOIUrl":"https://doi.org/10.2118/0616-0002-OGF","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75033906","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Underground Bacteria Generates H 2 S and Trips Control Panels","authors":"T. Subramanian, Khaled M. Adel, I. A. Awadhi","doi":"10.2118/177798-PA","DOIUrl":"https://doi.org/10.2118/177798-PA","url":null,"abstract":"The building, having approximate dimensions of 42-m length, 9.7-m width, and 5.2-m height, is constructed of reinforced concrete walls and roof, and is designed to be blast resistant. There are four rooms in the building: the control room, which houses the instrumentation panels; the uninterrupted-power-supply (UPS) room, which houses the UPS equipment; the battery room; and the HVAC room. The panels in the equipment room are mounted on raised access flooring (false floor), having space for cables running underneath. The plan view of the building is shown in Fig. 1. The panels in this building tripped frequently, leading to unplanned plant outages, and thereby posing a risk to overall plant operations and integrity. It was observed that tripping of panels was mainly caused by failure of the electronic cards in the panels. Multiple cards had to be replaced, depending on the failure, and the rate of replacement was once in an approximately 1-month interval. Visual inspection of the cards did not indicate any defect. Site survey observations indicated a mild odor of H2S prevalent in the vicinity of the building and in areas under the false floor, discoloration of soil surrounding the building, high groundwater levels, and damages to building cable-entry sealants. To investigate the root cause and provide remedial measures, a technical study involving several testing techniques was carried out and the root cause was identified. Remedial measures were proposed to overcome the issue and were implemented at site. This paper presents the tests carried out during the study, the test results, and the recommended remedial measures and their implementation and effectiveness, which enabled mitigation of the failure of the control panels.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85874857","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Statoil: Subsea Compression Systems To Extend Field Life","authors":"S. Whitfield","doi":"10.2118/0616-0001-OGF","DOIUrl":"https://doi.org/10.2118/0616-0001-OGF","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80739563","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CO 2 Capture and Usage: Harnessing the CO 2 Content in Natural Gas for Environmental and Economic Gains","authors":"Emmanuel O. Agiaye, Mohammed Othman","doi":"10.2118/178316-PA","DOIUrl":"https://doi.org/10.2118/178316-PA","url":null,"abstract":"power generation, as capable of contributing up to 19% in CO2 reductions (IEA 2008, page 69). These are not withstanding the assessment performed by IEA (2012) with respect to “high potential CO2 emissions” found with global “carbon reserves,” and thereby outlining the deployment of CCS as the major technology required for sustaining the projected demand on fossils. “The assessment has attributed almost 63% to coal, 22% to oil and 15% to gas in CO2 emissions potential locked in these reserves.” The case of CO2 in natural gas represents a typical scenario for a number of oil and gas companies faced with the enormous challenge of reduced energy level of sales gas making it subquality or when disposal by flaring increases the source of CO2 emissions to the atmosphere. However, the amount of natural gas flared globally has been shown to contribute approximately 1.2% of the global CO2 emissions, which is given to be more than one-half of the certified emissions reductions under the Kyoto Protocol (ICF International 2006). There are several technologies and techniques now available for separation of CO2 (or acid gases) from gas mixture, either as flue gas from power plants or from natural gas. In addition to deployment of these technologies, the captured or separated CO2 must be disposed of in such a manner as to prevent it from seeping back into the atmosphere. This is required to achieve the aims of the CDM from the use of fossil fuels. Among the fossil fuels, natural gas has been shown to contain the least amount of CO2 emitted per tonnage of fuel burnt as compared with coal and oil. In addition to the CO2 emitted during combustion, natural gas on production also contains a certain amount of impurities, including CO2 gas. The maximum level of CO2 permitted in natural-gas fuel is typically less than 3%. Hence, all natural gas is treated to remove the solids and free liquids and to reduce water-vapor content to acceptable levels and, especially, to meet pipeline specifications. Hence, natural gas must be purified through the removal of CO2 and other acid gases and impurities (where present) because these impurities can form acids in the presence of water to corrode pipelines and other equipment. In addition, higher concentrations of CO2 in natural gas reduce the heating value or energy level, which is below pipeline specifications, necessitating its removal before distribution to the end consumer. Natural gas has been a main source in meeting the world’s energy demand, contributing an estimated 23.81% in 2010 to the world energy supply mix (Rufford et al. 2012, page 123). This contribution is projected to increase because natural gas is considered the cleaner fossil fuel compared with coal and oil. The deployment of appropriate CO2-capture technology in processing natural gas stands to improve its value as the cleaner fossil fuel. In this paper, a brief review of related acid-gas separation processes will be reviewed and recommendations will be presen","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79028643","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Savvy Separator Series: Underperforming Gas Scrubbers—How To Fix Them and How To Avoid Them","authors":"Elizabeth Morillo, V. V. Asperen, G. BaarenSander","doi":"10.2118/0416-0016-OGF","DOIUrl":"https://doi.org/10.2118/0416-0016-OGF","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2016-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82117856","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}