Day 3 Wed, December 12, 2018最新文献

{"title":"An Integrated Approach to Characterize Heavy Oil in Complex Clastics-A Case Study From Southern Part of India","authors":"Srimanta Chakraborty, Anjana Panchakarla, C. Deshpande, S. Malik, P. S. Majithia, S. Chaudhary, A. Murthy","doi":"10.2118/193696-MS","DOIUrl":"https://doi.org/10.2118/193696-MS","url":null,"abstract":"\u0000 Conventional volumetric analysis has its own limitations & challenges to characterize fluid types in complex clastic reservoirs. Presence of shale and radioactive minerals in sandstones makes the evaluation more complicated compared to clean reservoirs as uncertainty become higher to ascertain grain density & total porosity. Delineation of pay zones (heavy oil bearing) & estimation of saturation become more uncertain due to reservoir complexities.\u0000 Elemental spectroscopy log can provide real time grain density, TOC (Total Organic Carbon) and mineralogy for complex reservoirs (radioactive sand). However, to determine the fluid type and porosity in this type of reservoir, Nuclear Magnetic Resonance (NMR) would be the best choice due to its capability of recording simultaneous T1 (Spin-lattice relaxation time) and T2 (Spin-Spin relaxation time) including diffusivity measurement sequences. Compare to the traditional 1D T2 spectrum based interpretation methodology; A new approach of using constrained 2D NMR inversion, enhances the capability to discern different fluid phases by mapping proton density as a function of T2 relaxation time (T2int) in the first parameter dimension and diffusion coefficient \"D\" (or T1 relaxation time or T1/T2app ratio) in the second parameter dimension. An integrated approach is used by combining NMR and Elemental spectroscopy results to reduce formation evaluation uncertainties in heavy oil reservoirs.\u0000 Successful integration of NMR, Elemental Spectroscopy Log with Image and Acoustic results helps to understand reservoir properties in study area. The advantage of using constrained 2D NMR over conventional 2D NMR reduces the uncertainty of responses between Clay Bound Water (CBW) and heavy oil, which has similar T2 relaxation mechanism. Integration of Clay volume from Elemental Spectroscopy measurements in constrained 2D NMR helps to differentiate the heavy oil and clay bound water responses. Furthermore, the combination of NMR & Elemental Spectroscopy results helps to segregate the existence of heavier oil & lighter oil components in the reservoir. Based on these results, potential hydrocarbon zones was identified and successful testing attempts were made.\u0000 This paper shows an approach of using constrained 2D NMR results over conventional 2D NMR to overcome reservoir uncertainties & to identify potential pay zones.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"53 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134549468","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":"Heavy Oil Enhancement Process for Deep Heavy Oil Reservoir in Kuwait Field","authors":"Noor Mohammed, Hamad Al-Rashidi, Abdul-Aziz Safar, Bruce Duncan, Asma Al-Sagheer, Batoul Muhsain","doi":"10.2118/193666-MS","DOIUrl":"https://doi.org/10.2118/193666-MS","url":null,"abstract":"\u0000 Kuwait is in the process of developing the deeper heavier oil reservoirs as part of Kuwait's national oil production strategy and KPC strategy 2040. This is in order to increase the oil production capacity for the next decade. The enhanced recovery of heavy oil assets needs a high level of expertise, optimum technologies and techniques, which are tailored to the distinctive challenges of the reservoirs and performed in a cost effective manner to optimize output and maximize economic benefits and rate of returns.\u0000 Several wells are perforated in the zones of interest of the reservoir within the study area, which is currently under production using Progressing Cavity Pumps and is under natural production phase. The low productivity oil producers are completed in the Burgan reservoir. This reservoir is characterized by very high viscous crude oil around 15,000 cp, with a low gas-oil ratio (10-30) and with little or no primary drive mechanisms. The project requires overcoming certain challenges the following challenges are identified as the key challenges:\u0000 Limited fluid mobility which is due to the high viscosity of the oil. Absence of drive support associated with the dissolved gas, the depth of the well, and the oil and its compositional gradient reservoir. Non-thermal well completion of the well, and the perforation design policy that was implemented. Lack of fluid/rock characterization and being in an oil-wet system.\u0000 In the design of this project, the suggested method to be used is a non-thermal optimization process \"chemical treatment \". The chemical treatment will be implemented as the chosen technology for a well that ceased producing in 2009. This method which has been applied globally and has also been proven to have less impact on the environment as per KOC HSE policy. The selected environmentally friendly method has three important mechanisms, which are as follows:\u0000 Acts as a Wettability alteration agent. Acts as a Viscosity reducer agent. Acts as an Asphaltene inhibitor agent.\u0000 KOC successfully conducted a pilot in 2016 and after the well was put back on to the production phase an increase of 300 bbl/day (net oil) was attained. The return of investment (ROI) of this pilot was a key economic calculation in answering the economic benefits of this procedure and in validating the project. As well showing the economic benefits of the projects value and its impact on the margin. The return of investment (ROI) was captured within day of production, with the total profit for the first 34 days was 438,885.52 USD.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130537193","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":"Generation of BFW Using Bacteria Containing Reject Streams from Municipality Sewage Plant - Kuwait and Related Challenges to Meet Set BFW Spec","authors":"R. Ghouti, C. Kuijvenhoven, Ealian H.D. Al-Anzi, Meshari M Al-Hasan","doi":"10.2118/193682-MS","DOIUrl":"https://doi.org/10.2118/193682-MS","url":null,"abstract":"\u0000 The South Ratqa heavy oil field, located in the Northern part of Kuwait, will be developed thermally with the first phase of the development expected to become on stream in 2019. The water source to make up steam is coming from the Municipality Sewage Plant Sulaibiya (SWWTP) located in Kuwait City. The Sulaibiya plant is handling sewage water which is locally treated to make it suitable for further use. In the treatment process, RO units are used, and the reject stream of those RO units was identified as water source for the steam plant in the South Ratqa field.\u0000 In total six steps are required to cover the full treatment scheme of the Boiler Feed Water (BFW) plant, namely: (a) Water Clarifier and sludge treatment, (b) Multimedia and Ultra filtration, (c) Ion Exchange, (d) double Reverse Osmosis, (e) Ozone and Ultra Violet treatment and (f) finally De-aerator. Currently, the plant is being constructed as part of the first phase of the South Ratqa thermal development. Control of bacteria was identified early in the design phase to be crital to ensure successful operation of the BFW plant with minimal down time. Bacteria control will be done at two locations: Upstream of the BFW plant: chemical control of bacteria growth with chlorine addition.Within the BFW plant: mechanical bacteria control using a combination of ozone addition and UV.\u0000 Upstream of the BFW plant, chlorine will be added in the Sulaibiya plant located 123 km from the South Ratqa field. The project team realized that the added chlorine at this plant would not be enough to fully limit bacterial growth throughout the 123 km pipeline and more importantly, the growth in the 3 storage tanks upstream of the BFW plant. It was then decided to add extra chlorine injection capacity in the BFW plant just before the storage tanks. A suitable test protocol was developed to define the required extra chlorine demand resulting in a residual chlorine level between 0.5 and 2 mg/l entering the BFW plant and taking into account the extra residence times in the process.\u0000 The extra injection capacity is currently under design. With the help of this extra chlorine addition bacteria growth will be under control and the required high BFW plant availability can be achieved.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134299128","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":"Analytical and Numerical Models Assist in Water Production Management in a Heavy Oil Reservoir in Northern Kuwait","authors":"Asrar Al-Shammari, A. Kharghoria, J. G. Garcia, Pabitra Saikia, Abdulrahman Fares Al-Shammari, Abdullah Abdul Al-Rabah, Hisham Husain, Devesh Kalia","doi":"10.2118/193694-MS","DOIUrl":"https://doi.org/10.2118/193694-MS","url":null,"abstract":"\u0000 A comprehensive numerical and analytical assessment of water coning in a heavy oil field in Northern Kuwait is presented in this study. Several wells were investigated in light of possible coning affect. Based on the lessons learned from the field data and modeling efforts, a coning envelope is generated and possible mitigation actions are explored. The complex geologic and stratigraphic architecture of the reservoir with underlying oil-water contact presents a unique challenge to achieve water-free oil production in this field. The field produces average 150 API crude of 50-100 cp at 100° F.\u0000 Production data from wells from different structural locations were history-matched using numerical simulations on single well models (including type well models). Model runs were extended to estimate critical liquid rate to avoid coning. Additionally, critical rates assessed from several analytical models were compared against those from the numerical simulations.\u0000 Critical liquid production rates for different areas of the field have been assessed based on the coning envelope generated. Further works showed that the critical rate is also a strong function of operational, reservoir and fluid parameters as well as completions standoff from current oil-water contact (OWC). Since the current oil API is very close to that of water, the critical rate is not a strong function of the density difference of the reservoir fluids, however, difference in the fluid viscosities displayed a some degree of impact on the coning rate. Operational results also showed that average of 15 ft standoff from the existing OWC is critical to avoid imminent coning. This presents an important opportunity for efficient completion decisions of a candidate well. The most significant new finding is that two analytical models evaluated during this study indicated that these models have limited capability to assess the critical rate from the heavy oil reservoir, and appear to have high degree of sensitivity to oil viscosity.\u0000 This paper provides an integrated approach to assess and manage water cone in a heavy oil recovery project. Generated coning envelope provides a tool for a proactive strategy for rate management including opportunities for strategic well completion decisions. Another noteworthy assessment is that the existing analytical models have significantly limited capability to model water coning behavior in a heavy oil reservoir.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130324491","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":"Production Data Management Collaboration Effort in an Integrated Journey for More than 1,000 Wells in the Northern Kuwait Heavy Oil Fields","authors":"S. González, Tamadhor Al Muhanna, Waeil Abdelmohen Abdalla, D. C. Pandey, Ahmad Naqi, Loloh Al Mezal, Aisha Al Saqer, S. Rajab, A. Safar, Greg Gonzalez, Satinder Malik, I. Fadul, A. Hamlaoui","doi":"10.2118/193762-MS","DOIUrl":"https://doi.org/10.2118/193762-MS","url":null,"abstract":"\u0000 Based on the North Kuwait Heavy Oil fields’ development plan, by the end of 2019 more than 1,000 wells will be connected to the producing facilities. An extensive amount of surface and subsurface data will be collected and transmitted to the central databases.\u0000 This paper describes the Data Management processes and workflows currently in place not only to use the captured and analyzed data for production and facilities optimized and safe operation but also the strategic plan for future integrated wells and facilities management. Different approaches for both at wells and surface facilities data sets are being implemented not only to monitor and optimize the wells and field performance but also to provide other disciplines with the right data in the right format at the right time.\u0000 The vision is to move away from the current approach to a new one to handle automated real-time data capture, data analysis, data visualization and Exception Based surveillance within the domain of CWE (Collaborative Work Environment). A single data repository has been used to ensure seamless communication from the field facilities and wells directly to the end-user workstations. Data algorithms are run in daily basis to detect anomalies in millions of data point of parameters allowing either proactive interventions or understanding the reasons for deviation from normal expected operating parameters.\u0000 By implementing a daily surveillance routine and simple exception-based monitoring rules along with advanced data algorithms on wells (including artificial lift system) and facilities parameters, it was possible to detect wells without production, production recirculation due to holes in the tubing, flowlines plugging and downhole sand issues. The importance of Data Management falls into predictive analysis techniques focused on increasing the uptime of wells and facilities, supported by typical data science algorithms such as clustering, advance filtering, detection of data anomalies, regression and classification.\u0000 This paper will also discuss how a holistic approach has evolved in managing the current operations, capture the lessons learned for not only optimizing the current field operation but also use the knowledge gained for future development strategy; the result: an approach to a collaborative environment to help the team to analyze performances, make decisions and create strategies to increase production, reduce lead time and reduce costs.\u0000 The Production Data Management strategies implemented in the early stages of the project have already generated significant value in picking up and prioritizing wells with issues, detection of flowline plugging, and Artificial lift system issues resulting not only in maintaining the production plateau but also reducing operating expenses while improving the restoration time.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"86 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"120936982","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":"Solving 12-1/4-in. Directional Drilling Challenges by Minimizing Stick/Slip Vibrations in North Kuwait","authors":"Karim Beheiry, Mohammed Al Mulaifi, Anish Sekhri, N. Farhi, W. Nouh, Ahmed Abdel Naby, Abdullah Marafi, Atef Shatta, Hussain Al-Ali","doi":"10.2118/193807-MS","DOIUrl":"https://doi.org/10.2118/193807-MS","url":null,"abstract":"\u0000 The 12-1/4-in. directional application is one of the most challenging applications in North Kuwait. The section requires drilling from the Mutriba (Santonian) to Burgan (Albina) formations through highly interbedded, high-compressive-strength carbonates (limestone and dolomite), sandstones, and shales. In recent years, Kuwait Oil Company (KOC) has tested many different bit designs in an attempt to minimize stick/slip vibrations and maximize the rate of penetration (ROP). This paper presents the technology used to nearly eliminate stick/slip vibrations, leading to a field record (and a consistent performance) for this application, as well as the process used to develop the technology.\u0000 The interval was drilled using a rotary steerable system (RSS) to maximize wellbore quality and to provide consistent build-up rates (BUR) required. Parameters run in this application are often limited because stick/slip becomes uncontrollable when transitioning through the many formation types. In addition, reactive and stressed caving shales are regularly observed in the Ahmadi and Wara formations drilled during the interval. Special care is needed to mitigate these drilling challenges and to successfully drill the interval with low stick/slip vibrations and high ROP.\u0000 Using proprietary state-of-the-art design and analysis technologies, a new polycrystalline diamond compact (PDC) bit was designed for use specifically with RSS tools to minimize the vibrations. The solution required a thorough offset analysis before the interval that was presented using the design process. The design process enabled the presentation of a driller's roadmap to be used in conjunction with the new bit to enable a benchmark ROP to be achieved.\u0000 The use of the newly designed PDC bit produced minimal torsional vibrations, enabling a 62% increase in ROP over the field average. This increased ROP resulted in a savings of USD 90,000, reducing the cost per foot by 33%, as compared to the field average. The bit also came out in excellent condition, enabling future use in similar applications for KOC.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114394846","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":"New Technologies Enhance Efficiency of Hydraulic Fracturing Stimulation in Heavy Oil Reservoirs","authors":"B. Cai, Duan Guifu, He Chunming, Gao Yuebin, Li Yang, Xu Zhihe, Jiang Wei","doi":"10.2118/193663-MS","DOIUrl":"https://doi.org/10.2118/193663-MS","url":null,"abstract":"\u0000 X oil field was located in eastern China. The lithological component of formation is fine sandstone. The typical characteristics are low-permeability and low-porosity with high viscosity, resin and asphaltene contents, the detail characteristics as follows:1)Shallow buried depth (650~850m); 2)Low permeability and low porosity(the average permeability is 1.0×10−3μm2 and the average porosity is 10%); 3)High oil viscosity,asphalt and wax content (15.2 API,24.3%and17.8%,respectively);4)Ultra-low temperature(45~53°C) with high solidify point(nearly 30°C);5) High content of clay (from 14 to 23%)and high content of velocity-sensitive minerals such as illite, almost 80 percent of wells need hydraulic fracturing treatment, therefore, hydraulic fracturing stimulation is an important technology for this tight heavy oil formations. Over the past two decades, conventional fracturing treatment has far away from satisfaction as a result of high viscosities, poor flow properties and high solidify point in compared to conventional oil. Therefore, a systematic technologies are put forward in this paper, the highlights are:1) Systematic fine formation evaluation prior to fracturing design which contains mineral gradients, nuclear magnetic resonance, rock mechanics, in-situ stress profile, X-CT scanning and so on; 2) A new finely processed pre-pad fluid is developed, and the asphalt and wax content can be reduced through completely miscible between oil and fluid interaction; 3) Low polymer concentration fracturing fluid and variable viscosities are utilized in different treatment stages. The concentration is only 0.2%-0.28% and residue content is 82mg/l reduced 45% and 35% that of the past fracturing fluid,4)Many fracturing treatment parameters are changed such as proppant's type and size, fracturing fluid's type, tip screen-out (TSO)fracturing in order to improve fracture conductivity, liquid nitrogen injection to pad fluid with multi-stage slurry injection schedule, and pumping rate as well, which makes it not only to ensure the successful treatment but also to maximize fracturing treatment potential; 5) Counter measures are applied systematically such as systematic quality control, optimization shut-in time for improve propped profile and flow back, post-treatment management, etc.\u0000 More than 120 treatments with new technologies in X tight heavy oil field have been performed with encouraging results,95% efficiency with accumulated incremental oil of 110,500 tons and the average post-fracturing rate reach to 10.5m3/d increased more than 50% that of the past well stimulation under the same formation conditions.\u0000 The novel hydraulic fracturing technology provides a new way to maximize recovery efficiency with in low-permeability heavy oil reservoirs. It also has important strategic significance for development and exploration promotion of these unconventional reservoirs.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"193 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132837668","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 Data Analytics to Improve Drilling Performance and Manage Drill Stem Vibrations","authors":"Mohammed F. Al Dushaishi, S. Hellvik, A. Aladasani, M. Alsaba, Q. Okasha","doi":"10.2118/193779-MS","DOIUrl":"https://doi.org/10.2118/193779-MS","url":null,"abstract":"\u0000 Data mining and Artificial Intelligence (AI) methodologies are underdeveloped in the oil and gas industry, despite the need to improve drilling performance and remain globally competitive in all capital-intensive projects.\u0000 Drilling companies allocate significant resources to improve well planning, drilling schedules and rig management. Well planning comprises of two main elements; drilling performance and the reduction of drill stem vibrations. Therefore, modeling methodologies such as drill string statics, dynamic tools and rate of penetration modeling are applied to determine the optimum bottom hole assembly (BHA) components and drill bit design. However, more attention is required on drill stem fatigue, non-productive time (NPT) and their impacts on drilling operations.\u0000 In this paper, Data Analytics (DA) is applied to drilling logs taken from three wells that recorded vibration readings from different geological stratification. In turn, the work in this paper establishes a relationship between drill stem vibrations and various measurement and logging data while drilling. Statistical regression and multivariate analysis were used to examine correlations of drilling parameters, including BHA assembly, to vibration data. Therefore, the results include a composite vibration model that describes the drilling stem vibration behavior as a function of drilling parameters, and geological formations.\u0000 Results of the vibration models built in this study indicate that the drill stem lateral vibration behaves parabolically as a function of the drill pipe length, length of drill collar, gamma ray (GR) response, and weight on bit (WOB). The analysis of drill stem vibration effect on the mechanical specific energy (MSE) was inconclusive for depths below 1350 meters. However, for depths above 1350 meters a strong correlation was observed to ROP.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132114927","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":"Simultaneous Occurrence of Miscible and Immiscible Displacement Processes During Solvent Displacement of Heavy-Oil: A Parametric Analysis Using Micro-Scale Experiments","authors":"Yu Shi, T. Babadagli","doi":"10.2118/193702-MS","DOIUrl":"https://doi.org/10.2118/193702-MS","url":null,"abstract":"\u0000 Oil-solvent mixing is essential during solvent injection applications to reduce the viscosity of oil but mass transfer by diffusion becomes slower as the oil becomes heavier. Thus, an interface exists between oil and solvent at certain times being stronger in the beginning of the process. This results in an immiscible displacement controlled by the capillary forces while mixing is in progress. It is of practical and fundamental importance to determine the mechanisms responsible for the displacement of heavy oil and the behavior of solvent (acting as both immiscible and miscible displacement agent) as it could be advantageous to accelerate the dilution of heavy oil in many circumstances, including heterogeneous (fractured, layered, wormholed) systems. This is a complex process consisting of multiple pore phases (oil, solvent, their mixtures, aqueous and vapor phases) at the same time while different mechanisms such as capillary imbibition, miscible interaction (diffusion and convection), and gravity also act simultaneously.\u0000 To investigate this complex phenomenon for different oil-solvent systems, a novel experimental method was employed. The underlying mechanisms that dominate the solvent displacement process were comprehensively identified. The movement and evolution of interfaces among different fluid phases in glass capillary tubes was observed and recorded. The oil samples with different viscosities were utilized to examine the effects of oil viscosity on the mass transfer accelerated by imbibition transfer. The effects of temperature, wettability and boundary conditions on the interaction of miscible fluids pairs were also studied. Pentane, heptane and decane were used as the solvent phases. Advanced photographic techniques using UV light and dyed fluids were applied to better track the flow of different phases in the mixing zone.\u0000 The experiments demonstrated a slowly smearing interface between solvent and viscous oil. A unique natural convection was induced with the combined effect of gravity, diffusion (mixing) and capillarity all contributing to the recovery of heavy-oil. Based on the saturation method, boundary condition and the Bond number, four different motion modes of mixing zone and interfaces of miscible fluids in the capillary tube were unveiled and categorized to identify the degree of interface development (immiscible flooding). Also, the mixing zone, mass flux, and flow behavior were quantified using dimensionless parameters. The results indicate that priority may be given to a solvent with a high interfacial tension for solvent-based oil recovery technique because of a strong imbibition and further enhancement of the dilution and displacement processes under condition of similar viscosity ratio. The data provided will be useful for the accuracy of modeling studies, especially for complex geologies where oil-solvent interaction is critically difficult to develop in order for mixing to occur.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"199 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114187349","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":"Improving Sucker Rod Pump Performance and Overall Production After Applying Continues Steam Injection in Heavy Oil Project-North Kuwait","authors":"F. Abdulhadi, F. Al-Ajeel, Tomas Sierra, A. Mohamed, K. Heshmat","doi":"10.2118/193800-MS","DOIUrl":"https://doi.org/10.2118/193800-MS","url":null,"abstract":"\u0000 The manuscript focuses on benefits realized in sucker rod pump system performance, number of workovers, downtime periods, and overall production efficiency as a result of continuous steam injection (steam flooding) on a heavy oil pilot field. It also presents benefits on production performance as a result of real-time well optimization of sucker rod pump systems.\u0000 Implementation of real-time production optimization techniques to record behavioral changes provide for up-close field operational surveillance (allowing for faster response time).\u0000 The steam injection effect varies from between locations, based on the distance between injector and producer wells, along with the degree of down-hole interference.\u0000 The objective was to study steam injection effects on a group of wells and adjust the operational parameters of sucker rod pump systems based on individual well performance conditions. Real-time wellsite monitoring (including creating notifications, warnings and alarms to identify troublesome or non-optimized wells) and data-trend analysis allowed us to make necessary corrective actions continuously, which led to an improvement in well performance since steam injection started (thus optimizing productivity).\u0000 The continuous steam injection, supported by real-time optimization and constant sucker rod pump system performance adjustments, led to the following operational efficiency improvements: Reduced downtime related to troubleshooting activitiesReduced pump replacements (obtaining longer run life of downhole equipment)Improved pump efficiency (measured by improvements in production rates)Created a workflow for sucker rod pump system performance review and optimization opportunitiesImproved field-wide overall productionImprovement in sucker rod pump system efficiency (pump efficiency dyna card analysis was significantly improved in wells with low pump submergence after steam injection)\u0000 Maintaining the same downhole pump configuration, we found that pump efficiency (calculated by measured production rates) changed significantly: from low efficiency before steam injection (on colder periods) to higher efficiency (after steam injection). We also studied pump performance during the production phase and adapted the sucker rod pump system operational parameters to the wellbore's changing operation conditions, driven mainly by wellbore's temperature changes.\u0000 Applying continuous steam injection in a heavy oil area supported in improving pump performance, reducing downtime, and improving overall production from a specific number of wells, compared to lower production and higher downtimes (with larger number of wells), but without continuous steam injection.","PeriodicalId":137875,"journal":{"name":"Day 3 Wed, December 12, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131308506","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}