Day 2 Tue, October 16, 2018最新文献

{"title":"Ahead of the Bit Pore Pressure Prediction under Centroid Effect Conditions Using Express Seismic Processing Results for Exploration Drilling in the Caspian Sea","authors":"Nikolay Smirnov, I. Kerusov, A. Aristarkhov, M. Sokolova, N. Evmenov","doi":"10.2118/191498-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191498-18RPTC-MS","url":null,"abstract":"\u0000 For the offshore prospecting and appraisal well drilling optimization, an approach was proposed, included Pore Pressure prediction based on 2D processing of a seismic surface data. This approach was used for timely detection of sharp changes in Pore Pressure with depth, under expected «centroid» effect for a well construction in the waters of the Caspian Sea.\u0000 At the initial stage, an acoustic inversion of 2D seismic data wascarried out. Based on the obtained acoustic impedance section and seismic velocities, after a deep migration, Pore Pressure forecast was conducted for the well area. Pore Pressure was restored for the offset well and relations between effective stresses and seismic inversions results were identified for different facies. Together with the geomechanical support, regular velocity-depth model updating process was realized, involving log and well data from drilled section.\u0000 Using the velocity-depth model, updating process and continuous support, Pore Pressure forecast was successfully implemented in the intervals with sharp pressure variations. Bottom-hole updates were carried out in the critical further drilling intervals using updated formation velocities and seismic attributes, to the depth of next drilling section. In real time, the pronounced regional centroid effect was confirmed and successfully passed. Directly during the drilling, casing depths were corrected, mud weight values and equivalent circulation densities were controlled in safe ranges. In this work, regional centroid effect was predicted and verified for the Caspian Sea area.\u0000 The completed project demonstrates the successful application of a process involving tomographic update of velocity-depth model and continuous Pore Pressure forecast for optimization and increasing offshore prospect well drilling safety. This approach is critical for successful well construction under centroid effect, particularly, in the Caspian Sea area.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128471894","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":"Research and Development of the Lightweight Corrosion-Resistant Cement Blend for Well Cementing in Complex Geological Conditions","authors":"Sergei Kamenskih, N. Ulyasheva, G. Buslaev, A. Voronik, N. Rudnitskiy","doi":"10.2118/191509-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191509-18RPTC-MS","url":null,"abstract":"\u0000 Is a fact that well cementing in highly permeable rocks is complicated by a high content of hydrogen sulfide, overoming a large number of difficulties. There is an accelerated destruction of cement stone, the absorption of the cement and the impossibility to reach its level of design in the annular space, which leads to a significant problems and failures at the cement performance and as a result to the casing leak and remedial cementing techniques. We are going to present the results of the analysis and laboratory testing, evaluation and analysis of cement slurries for fixing high-permeability rocks containing hydrogen sulfide. In the conclusion was revealed that there is no effective cement slurry wich will be solution with hydrogen sulfide resistance and qualitatively colmation ability of absorbing horizons. Evaluating the effectiveness of cement slurries and the cement sheaths was carried out through laboratory studies performed at the Drilling Department of the Ukhta State Technical University\u0000 Laboratory testing to determine chemical characterization and performance evaluation of cement slurries and cement sheaths were carried out using both standard Russian and foreign testing procedures and equipment for cement testing according to GOST and API standarts. In addition, the cement sheath integrity for corrosion was testing according to the procedure proposed by Doctor of Science Victor Solomonovich Danyushevsky using the corrosion resistance coefficient. Based on the laboratory testing, evaluation and analysis, it was designed a new composition of lightweight corrosion resistant cement slurry (application for invention № 2016117871 of 05.05.2016) on the basis of Portland cement IG HSR-1, treated with the sulfated synthetic polymer (Gas block), expanding additive (EA) and granulated foam glass (GFG). The addition of granular foam glass makes possible to reduce the density of the cement, in order to improve the efficiency of pore and cracks colmatation upon high permeability rocks acting as a necessary expanding additive. The treatment of cement slurry by gas acting blocking additive decreasing permeability of the cement sheath, as a result, the quality of the wells barriers increases under the conditions of hydrogen sulfide attack. In general, the lightweight corrosion-resistant blend allows to reduce the permeability of cement sheath and to use it for improve the quality of cements contaning hydrogen sulfide coming from highly permeable rock layers. Established and defined physic-mechanical properties and parameters of the blend and cement stone, their changes with variation of the concentration and dispersion of the granulated foamed glass. With the corrosion resistance factor was found that designed cement slurry and sheath have a corrosion resistance to hydrogen sulfide attack. In conclusion the operations manual for the second intermediate and production casing string for exploratory wells at the Alabushin field was compiled. In this ","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"22 3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123749680","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":"Determination of the Optimal Bottomhole Pressure in Order to Reduce the Removal of the Solid Phase in the Weakly Consolidated Reservoir","authors":"I. Chebyshev, Alina Shapovalova, S. Zhigulskiy, S. Lukin","doi":"10.2118/191625-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191625-18RPTC-MS","url":null,"abstract":"\u0000 The elaboration of weakly consolidated terrigenous collectors is accompanied by considerable removal of the solid particles. At one of the reservoirs of Western Siberia technique of evaluation and forecast of the volume of the removed solid particles on the basis of Finite-element modeling was tested.\u0000 Suggested way to evaluate the volume of the removed particles includes multiple stages. Reconstruction of the dynamic, static properties of the deformation and durability with taking into account the textural features of the rock samples. Construction of the 1D geomechanical models in target layer and exceeding coal-measures. Creation of three-dimensional model of mechanical qualities for realization of further calculations for the well which is included in contour of 3D-model. Finite-element modeling of the part of the trunk of the well in poroelastic arrangement for evaluation of plastic effects which are arising in collector - sandstone and non-collector – aleurolite, argillite with fruit her calculation of the volume of the removed solid particles.\u0000 It allows to determine the safest bottom hole pressure for the highest possible conservation of the stability of the well type \"fishbone\".","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132590192","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":"Challenges of Cementing Steam Injection Wells SAGD","authors":"A. Figilyantov, O. Chugaeva, O. Garshina, G. Okromelidze","doi":"10.2118/191508-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191508-18RPTC-MS","url":null,"abstract":"\u0000 There are a number of high-viscosity oil fields around the world. A distinctive feature of such oil fields is a combination of two factors: high viscosity of oil and low temperature of its enclosing zone. Sometimes, the temperature of pay zone is comparable to the temperature of permafrost + 6 °C.\u0000 Thermal methods are used to intensify oil production in such oil fields. The main thermal method is the injection of steam into the formation. The temperature of the injected steam exceeds 200 ° C.\u0000 With using this technique of intensification, there is a challenge of keeping the integrity of the cement sheath behind the column, as the cementing conditions and operating conditions are incompatible. The curing of the cement stone occurs at a temperature about + 6 ° C. When the steam is injected, the cement sheath is heated to a temperature of + 195 ° C or more.\u0000 Thermal deformations of the columns occur: expansion, elongation, when high temperature is applied. To reduce the probability of steam breakdown due to thermal deformations of the column, thermo compensators are used. Moreover, to compensate for the thermal elongation, the shoe of filter pipe is set upper than bottom was drilled.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"62 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134227279","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":"Adaptive Option in Geological Modeling of Petroleum Reservoirs","authors":"E. Taraskin, S. Ursegov, Nikolay Taraskin","doi":"10.2118/191621-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191621-18RPTC-MS","url":null,"abstract":"\u0000 The adaptive geological model differs from the deterministic one in that it takes into account the uncertainty of the initial data, has a degree of detail corresponding to the level of accuracy of the geological information, and reproduces the main regularities of the structure of the oil and gas object under consideration, primarily for the purpose of predicting its geology in undeveloped zones. At the first stage, adaptive geological models of separate layers identified by the results of detailed correlation of the considered object are constructed independently from each other, and then the single-layer models are summed up into a multilayer adaptive geological model of the object as a whole. With the adaptive approach, traditional methods of interpolation of geological and production data are not applied. The basis of adaptive geological modeling is the seismic data. The essence is that the seismic data vector is available both at the wells and at the points of the inter-well spacing, so any geological parameter can be calculated from this vector using a special fuzzy-logic function. At the same time, such function cannot be the same for the whole model polygon, so an additional so-called fuzzy-grid is developed. A grid with large cells, which contain local fuzzy-logic functions. Since fuzzy-logical functions are formed on the basis of geological and production information of the considered object, they can differ substantially for other objects. Thus, the mathematical apparatus of a geological model automatically modifies to the specific initial data, and therefore it is called adaptive. The calculated parameters of the adaptive geological model cells through which the wells pass are not necessarily the same as the actual well data. The reason is that these parameters are calculated using functions in which the initial data of neighboring wells participate. Deviations of calculated results from actual data characterize the degree of \"defectiveness\" of geological and production information. Thus, the adaptive geological model in comparison with the deterministic one gives a more meaningful result both about the geological structure of the considered object and the degree of reliability of its representation.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127794537","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":"Experience in Implementation of Polymer Flooding on East Messoyakhskoye Oil Field","authors":"E. Zagrebelnyy, N. Glushenko, V. Komarov, G. Nemirovich, I. Ilyasov, D. Sugaipov, O. Ushmaev, N. Pleshanov, R. Iskhakov","doi":"10.2118/191569-18rptc-ms","DOIUrl":"https://doi.org/10.2118/191569-18rptc-ms","url":null,"abstract":"\u0000 Development of reservoirs with high oil viscosity is usually challenging because of requirement to apply comlex technologies for economical efficient oil recovery. East Messoyakhskoye oil field is a complex project both from geological caracteristics (viscous oil with viscosity 111 cP, highly heterogeneous reservoir with permeability 50-2500 mD, presence of gas cap and aquifer) and due to its remote location (arctic climatic conditions, no transport and industrial facilities).\u0000 Main reserves are located in reservoir PK, senomanian formation. At the field development plan stage calculations showed requirement of flooding for reservoir pressure maintenance, but waterflooding expected to be risky due to fingering and it was obvious that for efficient reservoir development enhanced oil recovery methods should be considered.\u0000 This paper presents choosen enhanced oil recovery strategy, the way passed in polymer flooding implementation and current results.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127235192","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":"First Application of Fiber Based LCM in Srednebotuobinskoe Oilfield, Russia","authors":"A. Belyakov, M. Panov, I. Shirokov, N. Silko","doi":"10.2118/191506-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191506-18RPTC-MS","url":null,"abstract":"\u0000 Lost circulation is one of the main causes of nonproductive time during drilling in Eastern Siberia. In Srednebotuobinskoe oilfield major challenges are related to severely fractured igneous rock intrusion. Drilling through this interval is associated with constant severe to total losses. As a result, drilling velocity may drop below one meter per hour. Significant reduction of drilling time was achieved with application of an innovative fiber based LCM. Current paper describes results of this project.\u0000 Curing losses in severely fractured igneous rock formations is challenging. In most cases the fracture width is not known; it can only be predicted. However, this prediction is not always accurate.\u0000 An engineered fiber-based kill fluid was used to mitigate this lack of knowledge. Laboratory tests demonstrated ability to plug 1-5 mm fractures. System was applied in two wells in Srednebotuobinskoe oilfield. Fiber based pill was used in a combination with conventional LCMs. Additional operation time reduction was achieved by BHA compatibility. Average velocity of drilling through igneous rock interval was further compared to offset well from the same pad.\u0000 Drilling through 140 meters igneous rock interval of the well took around 147 hours. Conventional LCM are sensitive to fracture width. Due to geological complexity of the interval they had limited efficiency. A novel LCM based on soft, short fibers allowed to overcome this problem. It has a dual plugging mechanism. It can bridge across fractures up to 5 mm and form a filtercake on the formation surface, mitigating losses to the fractures network.\u0000 Applying this innovative solution in the 225 meters igneous rock interval of the second well (same pad) allowed to reduce drilling time to 119 hours. Thus, drilling became two times faster. Fiber based pill is also compatible with BHA, including telemetry. So additional time was saved on POOH/RIH operations. For the third well on the same pad pill placement strategy was further optimized. So, 135 meters igneous rock interval was completed in 23.5 hours. Drilling became 6 times faster comparing to the first well. Fiber based LCM showed high efficiency for mitigating severe losses in igneous rock intervals of Srednebotuobinskoe oilfield. BHA compatibility allowed to avoid additional POOH/RIH operations, providing extra value. Application of fiber based LCM led to significant acceleration of drilling igneous rock intervals.\u0000 The pill was prepared on the well site with equipment available. Compatibility with surface and downhole equipment was also confirmed.\u0000 Various successful field applications of fiber-based pills have been reported from various parts of the world. Current work presents first application of an engineered fiber based pill in Srednebotuobinskoe oilfield, Russia. The pill was pumped successfully in 2 wells in igneous rock intervals. Pill was placed through BHA. This solution allowed operator to achieve 6 times reduction of time required to ","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127004664","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":"Dynamic Fluid Diversion with Advanced Pressure Monitoring Technique – New Era of Multistage Refracturing in Conventional Reservoirs of Western Siberia","authors":"A. Borisenko, Sergey Parkhonyuk, E. Danilevich, A. Loginov, K. Butula, Andrey O. Fedorov, Dmitry Tetyuk, Aleksandr Kapkaev, R. Makhmutov, I. Tsygulev, K. Ibragimov, I. Letko, A. Mingazov, A. Volkov, Alexey Ivanov, I. Samoilov","doi":"10.2118/191710-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191710-18RPTC-MS","url":null,"abstract":"\u0000 Drilling of the horizontal wells in Russia is increasing both regarding the numbers of wells and meterage. Recently, one of the NOC reported 47% increase in a number of horizontal wells. It is clear now that shift towards horizontal wells completed with multi-stage hydraulic fracturing is increasing.\u0000 On the other hand, an economic lifetime of these wells not always met.\u0000 For the vertical well, a well-known and successful technique for the well revitalization is re-fracturing. Vertical wells have been responding so positively, that some operators perform refracturing up to four times on the same well.\u0000 In case of the horizontal well, one of the most significant uncertainties is the fluid entry point. Starting from uneven depletion of the horizontal part of the well, not knowing the fluid entry point may lead to ineffective well re-stimulation and absence of any positive effect.\u0000 In this paper, we will demonstrate integrated approach towards horizontal well re-stimulation: starting from proper reservoir evaluation and candidate selection to engineered treatment design. Several novel methods and techniques have been used: dynamic diverting agent, that has been developed to fit particularities of the conventional reservoirs, and high-frequency pressure monitoring technique, which has served as an engineering tool for fluid entry point validation.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126171369","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":"Cost-Engineering Waterflooding Management Methods","authors":"M. Naugolnov, N. Teplyakov, M. Bolshakov","doi":"10.2118/191580-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191580-18RPTC-MS","url":null,"abstract":"Optimization of the operation costs of Oil Companies in Western Siberia is the most important task of monitoring the development of oil fields. This is due to both: a decline in oil prices and an increase in the water cut in the production. Companies are forced to have large expenses associated with the organization of injection of the working agent to the reservoir pressure maintenance system, fluid lifting to the surface and operations on fluid dehydration. Often, the total value of operation costs forces companies to abandon the operation of wells, which negatively affects both the company's income and the level of oil production. The development of modeling tools opens up opportunities for companies to optimize key technologic and economic indicators of field development. This is especially relevant for old fields that are at the final stage of development, when the achievement of cost-effectiveness is impossible without constant optimization workovers. However, the geological uncertainties and the complexity of the correct evaluation of the reservoir simulation connection between the injection and production wells do not allow oil companies to receive a confident answer to the question of the efficiency of the current waterflooding system and individual injection wells. Unfortunately, the complexity of creating a permanent simulation model, which is connected both with the unreliability of input data, and with high labor and computational costs, does not allow to fully meet the requirements for optimizing the waterflooding system. At the same time, analytical methods, for instance, block-factor analysis (BFA) [1] despite its simplicity and flexibility, is not popular among reservoir engineers due to low prediction ability.\u0000 In this regard, there is a need to create a new engineering tool, which would simultaneously have a good predictive ability and would be rapid in use. Tools that meet these requirements include, for instance, analytical models that use database mining (data-driven methods). The use of these models allow estimate the value of the hydrodynamic connection between the producing and injection wells, make a retrospective analysis of the waterflooding system and make a reliable forecast of the production change when the injection changes using and tuning on history of operation modes of the wells.\u0000 The paper considers a hybrid reservoir simulation model based on the capacitance-resistive model (CM / capacitance-resistive model, CRM). The use of this model is based on training on history data, then testing the quality of training on test history data and subsequent forecasting development parameters. Based on physical processes, a simplified model of material balance with a minimum number of unknowns makes it possible to effectively predict the effect of injection wells parameters change. Also, this method allows, indirectly, qualitatively identify injectivity wells with unproductive withdrawal and, as a consequence, with a low p","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114955395","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":"Pore-Scale Imaging to Investigate Wettability and Recovery Mechanism for Surfactant/Polymer Flooding","authors":"M. Ahmed, A. Sultan, A. AlSofi, H. Al-Hashim, S. R. Hussaini","doi":"10.2118/191578-18RPTC-MS","DOIUrl":"https://doi.org/10.2118/191578-18RPTC-MS","url":null,"abstract":"\u0000 Surfactant-polymer (SP) flooding is a promising chemical enhanced oil recovery method in carbonates with high salinity brines especially where an existing waterflooding infrastructure is in place. SP flooding improves both the microscopic and macroscopic sweep efficiencies. The polymer viscosifies the injection water to control mobility, while the surfactant reduces the oil-water interfacial tension, and possibly alter wettability, to mobilize trapped oil. In this work, we investigate SP flooding recovery mechanisms in carbonates at the pore-scale.\u0000 Two polymers were used in this work: a Thermo-Viscosifying Polymer (TVP) and an Acrylamido tertiary butyl sulfonate (ATBS) with an acrylamide (AM) copolymer. Surfactants utilized were different grades of an amphoteric carboxybetaine. A set of four coreflooding experiments were performed at 90°C with a high-salinity injection brine (57,000 ppm). The first two corefloods investigated the independent performance of the chemicals (i.e. polymer flooding and surfactant flooding). The remaining two investigated the combined effects of SP flooding. The effects of different aging times were studied, too. Furthermore, micro-CT imaging were conducted at different steps both before and after flooding to evaluate saturation distributions and the chemicals effects on recovery. The images were also processed to segment the different phases which allows further evaluation of recovery mechanisms at the pore-scale.\u0000 Based on fluid occupancy maps, samples aged for one week exhibited strong water-wetness while samples aged for two weeks exhibited moderate water-wetness. In samples aged for one week, the final fluid occupancy was (i.e. remaining oil existed as) buckets of oil surrounded by water. While in samples aged for two weeks, the remaining oil was weekly attached to the surface of the pores. In terms of the recovery performance of the independent processes, the polymer flood showed better recovery than the surfactant flood. This supports the conclusion that in water-wet media the effect of surfactant alone is not significant if not coupled with mobility-control. In general, this work also demonstrates the utility of Micro-CT scanning in providing better understanding of recovery mechanisms at the pore-scale. With more accurate segmentation of the different phases, it can also provide a mean for in-situ contact angle measurements.","PeriodicalId":242965,"journal":{"name":"Day 2 Tue, October 16, 2018","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133247262","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}