Day 1 Tue, October 22, 2019最新文献

{"title":"A New Mixed Wettability Evaluation Method for Longmaxi Formation Shale in the South of the Sichuan Basin, China","authors":"Liang Tao, Jianchun Guo, Xiaofeng Zhou, A. Gayubov, A. Kitaeva, Chi Chen","doi":"10.2118/196931-ms","DOIUrl":"https://doi.org/10.2118/196931-ms","url":null,"abstract":"\u0000 Shale rocks are multi-component materials with complex interactions among different components. As a result, shale wettability evaluation becomes extremely difficult and knowing key factors that control shale wettability is particularly important for shale reservoir development. In this paper, wettability of both shale surface and pore of Longmaxi Formation in the southern Sichuan Basin were comprehensively evaluated by low field nuclear magnetic resonance (NMR) together with experiment; a new concept, mixed wettability index, was introduced to quantitatively evaluate the mixed wettability and clarify the key factors affecting shale wettability. The test results of wettability of different shale samples by the new method show that the surface of the Longmaxi Formation shale exhibits complex non-uniform mixed wettability, both oil-wet and water-wet, while the shale surface tends to be more oil-wet, the contact angles range from 15.9 ° to 63.7 °, with an average of 41.3 °, when tested with distilled water, and the shale is more water-wet under formation temperature. The shale pore also exhibit complex mixed wettability. The clay mineral content is the dominant factor affecting water wettability of shale, but when reaching beyond a certain value, it inhibits shale water wettability to some extent. The organic carbon (TOC) is the dominant affecting factor of oil wettability and positively correlated with oil wettability of shale. The research results are helpful for making clear the micro mechanism of the action between fracturing fluid and shale reservoirs and designing fracturing scheme.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128813635","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":"Technical and Risk Assessment of Underground Gas Storage Construction and Operation in China and Caspian Region","authors":"Jin Fu, Xi Wang, Chen Chen, Haowei Chen, Shunyuan Zhang, Bingshan Liu","doi":"10.2118/196911-ms","DOIUrl":"https://doi.org/10.2118/196911-ms","url":null,"abstract":"\u0000 Since China proposed \"Belt and Road\" initiative in 2013, Caspian countries have become a crucial region for oil and gas cooperation. However, it has been a common technical issue to develop presalt oil and gas resevoirs in the world. Caspian region is known for the wide-spread thick salt-gypsum formations. In China some old wells that were depleted due to engineering difficulties arising from presalt formations started to be developed as underground gas storages. The crude oil price has been keeping at a low level in recent years, which made China's government put more efforts in the development of underground oil storages in depleted salt caverns. As the largest project of underground gas storages, Jintan gas storage construction project successfully made best use of depleted salt caverns.\u0000 A Sonar test was applied on 4 Jintan underground salt caverns that are 900m deep and 1000m away from the surface in order to reveal their shapes. Salt and muddy salt rocks were collected in Jintan as samples to be analyzed in 3-axis pressure tests. Numerical results with finite element method (FEM) code ABAQUS were studied to approach the creep behaviors of caverns and rock pillars. The pressure arch model and the most dangerous sliding surface model were both utilized to optimize geometric parameters of the upper and lower walls of dissolved cavities.\u0000 Creep happens on salt rocks under deviator stress, which has non-linear relationship with time. In the simulated gas storage process the internal pressure went up to 14.0 MPa within 3 months but dropped to 7.0MPa in the following 3 months. The above condition may last for 9.5 years in real scenarios. Surrounding rocks of caverns deformed during construction but the most obvious creep was found at their tops and bottoms. Within 10 years salt pillars between caverns are under high deviator stress, thus their creep is the most serious. Surrounding rocks become unstable as the internal pressure of caverns decreases. The creep scope of salt caverns' tops was determined, because casing shoes shall be away from it in order to enhance the sealing quality. Shapes of dissolved cavities' tops are determined by minimum internal gas pressure which is inversely proportional to arches' heights if the span is given, while shapes of dissolved cavities' bottoms are determined by maximum internal gas pressure which is inversely proportional to stability coefficients of the most dangerous sliding surface. If the dissolved cavity's shape is given, the cavity is more stable with a higher cohesion. The maximum span of a cavity determines its stability.\u0000 It is the first time to use the pressure arch model and the most dangerous sliding surface model to optimize engineering parameters of underground gas storages in depleted salt caverns, which improves cavities' stability and optimized their shapes. Casing shoes used to be positioned directly above salt segments but now they are set away from the creep scope of salt rocks, which gre","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"131 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131460796","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":"Creation of a Source Rocks Integrated Petrophysical Model Based on a Special Core Analysis Results","authors":"A. Alekseev","doi":"10.2118/196926-ms","DOIUrl":"https://doi.org/10.2118/196926-ms","url":null,"abstract":"\u0000 Integrated petrophysical models have been broadly applied in geological and petro-elastic modeling to forecast hydrocarbon accumulations and to estimate resource potential. Methodological basis of building those models have been well developed for conventional terrigenous and carbonate reservoirs; as regards the so-called \"shale-type\" hydrocarbon-bearing rocks, however, there are objective difficulties determined by a range of various factors that may include multi-component composition of rocks, core recovery problems, as well as process-related peculiarities of laboratory methods. This paper offers a program of special laboratory core analysis of the samples from the Bazhenov formation and an algorithm for the processing of the results with the view to build an integrated petrophysical model of an unconventional \"shale-type\" oil pay.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133074373","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":"Assessment of the Potential of Low-Salinity Water Injection Technology to Increase the Oil Recovery of the Carbonate Reservoir of the Kharyaga Field","authors":"O. Zoshchenko, A. Aleshchenko, Y. Trushin","doi":"10.2118/196764-ms","DOIUrl":"https://doi.org/10.2118/196764-ms","url":null,"abstract":"\u0000 The development of carbonate reservoirs using peripheral and pattern water flooding typically achieves oil recovery factors ranging from 0.3 to 0.5, which is due to some complicating factors, such as, oil-wet surface of the pore space or the surface with intermediate type of wetting, unfavorable ratio of oil and water viscosities, presence of extensive structure of fractures, and significant variations of permeability down the reservoir section. In a complex geological environment, wells display abrupt fluctuations of water production that is an evidence of formation water being by no means the most efficient displacement agent. In these conditions, low-salinity water flooding can improve oil recovery.\u0000 This paper reports on SCAL results of oil recovery factor determination and spontaneous imbibition using water with different composition and total solinity for Object 2 of Kharyaga oil field. Also, report contains design of on-site determination of residual oil saturation using Single Well Chemical Tracer test technology for evaluation of EOR efficiency.\u0000 Laboratory tests showed, that low-salinity Jurassic water flooding with total salinity about 5 g/l could rase recovery factor up to 4% and also give incremental recovery due to effects of spontaneous imbibition for permability lower than 100 mD, which makes the injection of Jurassic water more preferable.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"118 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123235794","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":"Technologies for the Study of Full-Size Core with CT and Numerical Simulation Methods","authors":"D. Korost, V. S. Belokhin, A. Kudaev, A. Khomyak, Samvel Asryan","doi":"10.2118/196927-ms","DOIUrl":"https://doi.org/10.2118/196927-ms","url":null,"abstract":"\u0000 The work studies \"digital petrophysical\" technologies applied to the full-size borehole core. During the study various CT aspects were compared: the use of different CT systems, their key characteristics and principles of technological solutions, depending on the general technical conditions and possible tasks.\u0000 Special attention is paid to the modeling of real characteristics of sections according to CT data. The paper describes calibration procedures and subsequent calculations based on two-energy survey. The results obtained (volume density data stacks and Zeff) have high convergence with GIS data, profile and laboratory measurements.\u0000 Brand new results obtained on the basis of CT study of full-size core material are applicable both in the current petrophysical graphs of stone material processing and GIS interpretation settings. They also serve as a basis for the creation of digital models using the \"digital core\" technology.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128939140","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":"Sand Influence Analysis on ESP Operation in Salym Petroleum Development. Effective Methods and Procedures for Sand Protection","authors":"A. Shamkov, A. Gorlov","doi":"10.2118/196821-ms","DOIUrl":"https://doi.org/10.2118/196821-ms","url":null,"abstract":"\u0000 The current state of the Russian oil industry requires a scientific approach to optimizing the operation of electrical submersible pumps (ESPs) in harsh conditions. Most of the fields are at a late stage of development with high watercut and increasing amount of solid particles. At the new fields and new license areas the main share is made up of horizontal wells with multistage hydraulic fracturing, where sand removal from unconsolidated sandstone and proppant from the bottomhole zone of the well to the electrical submersible pump causes its serious damage and reduces the run life (Haiwen, 2019).\u0000 In many scientific papers mathematical models of the given process were described as well as the speed of wear of impellers and bearings surfaces as a result of influence of abrasive particles were defined in laboratory conditions.\u0000 At the same time, it is necessary to note insufficient elaboration of questions in estimation of derating rate of pump performance in high amount of mechanical impurities in field conditions, and as a result – the incorrect estimation of the period of effective and trouble-free operation of the submersible equipment.\u0000 The proposed researches, first of all, are directed on determination of the degree of influence of solid particles on impellers and diffusers of ESP, character and speed of wear inside an ESP, forecasting of optimum time of operation of ESP. Based on the example of Salym group of fields the analysis is offered, which can be adapted and applied at other fields.","PeriodicalId":143392,"journal":{"name":"Day 1 Tue, October 22, 2019","volume":"95 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126109627","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}