Day 1 Mon, December 10, 2018最新文献

{"title":"Optimization of a Thermochemical Recovery Process Using Global Optimization Methods to Enhance Heavy Oil Recovery","authors":"T. Moussa, M. Mahmoud, S. Patil, S. Elkatatny, K. Abdelgawad","doi":"10.2118/193791-MS","DOIUrl":"https://doi.org/10.2118/193791-MS","url":null,"abstract":"\u0000 Thermal recovery methods are viable and commonly used to recover heavy oil reservoirs by reducing oil viscosity and improving oil displacement. However, there are many challenges associated with conventional steam injection methods. These challenges include the significant heat energy losses before steam reaches the reservoir, the high cost of steam generation and injection, as well as the emission of greenhouse gases. Therefore, it is essential to introduce a heavy oil recovery approach in which steam can be generated downhole to overcome these challenges associated with conventional steam injection methods. However, this novel heavy-oil recovery method has several designs and operational parameters that must be efficiently optimized, to achieve maximum recovery from heavy-oil reservoirs with less cost and minimum environmental impact.\u0000 The objective of this work is to introduce a novel heavy-oil recovery technique using in-situ steam generated by downhole thermochemical reactions and investigate the key design and operational parameters of this complex recovery process. Modified self-adaptive differential evolution (MSaDE) and particle swarm optimization (PSO) methods are used in this work as global optimizer to find the optimum design and operation parameters to achieve the maximum net present value (NPV) and highest oil recovery (RF) of a heavy-oil reservoir after ten years of development. Comparison of the two proposed optimization methods is introduced as well.\u0000 The results show that downhole thermochemical reactions can be used to generate in-situ steam, to efficiently reduce the heavy-oil viscosity and improve oil mobility. It has also shown that utilizing MSaDE and PSO methods to optimize the key components of this novel recovery process, significantly enhanced the recovery performance, in terms of higher NPV and RF.\u0000 This study provides the first known in-depth optimization and uncertainty analysis to outline the significance of each design and operation parameter of the proposed novel thermochemical recovery process. This work showed and verified the concept of using downhole thermochemical reactions as an environmental-friendly solution to recover oil from heavy-oil reservoirs and is considered as a step forward to eliminate the greenhouse gases emission related to thermal recovery methods.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"38 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":"125089517","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":"Urban Planning in North Kuwait: Collaborating Across All Assets to Optimize Developments and Exploit Synergies","authors":"G. Warrlich, Khalid Al-Dohaiem, Ahmed Al-Boloushi, Hesham Abdelrahman, Vaidyula S. Kumar, Saad Al-Rashdan, S. Schrameyer, M. Cheers, B. Hulshof, Hamad Al-Haqqan, G. Reijnders, A. Al-Rabah","doi":"10.2118/193728-MS","DOIUrl":"https://doi.org/10.2118/193728-MS","url":null,"abstract":"\u0000 The Northern part of Kuwait is a highly active development area for deeper gas, intermediate-depth conventional oil and shallow heavy oil. All these developments have overlapping footprints in an already congested area, requiring different development concepts for gas, water flood and steam respectively. Additionally, different Assets manage the respective reservoirs. Integrated Urban Planning across all Assets therefore becomes a vital requirement for realizing all concurrent future developments regarding land use, and enabling close collaboration to leverage synergies among the Assets, utilizing both organizational and new technology-based solutions, in order to maximize value for Kuwait Oil Company (KOC).\u0000 In North Kuwait Urban Planning is a joint effort between KOC and Shell, with initial focus on establishing an agreement for work methods, effective communications, and protocols with all stakeholders. Next all \"as-built\" infrastructure and current plans were combined and reviewed. This formed the basis to identify and resolve conflicts, recognize opportunities for reduced land requirements and optimize the development synergies. The approach is underpinned with new technologies, tools, best practices, and concepts like multi-well pad developments, area discounting, exclusion zones, and shared infrastructure and road access corridors, based on global analogue developments.\u0000 In this paper example field ‘A’ is discussed as it has stacked reservoirs of shallow heavy oil, intermediate conventional oil and deep, sour gas. It requires significant urban planning focus to avoid conflicts and enable synergies. In field A, the shallow heavy-oil development requires large number of wells in a dense well-spacing versus fewer wells targeting the intermediate-depth conventional oil and deeper gas reservoirs, which requires large \"safety zones\" around well sites. In both cases, common infrastructure like roads, power distribution, flow line and trunkline corridors also need to be considered jointly.\u0000 Urban Planning collaboration between assets with distinct development challenges can help in creating safe co-development opportunities, thus maximizing value for KOC.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"197 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":"123034272","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":"Designing of a Groundwater Production Scheme for the Northern Oil Fields, Kuwait","authors":"H. Al-Enezi, Imad AlMuhaimeed, Meshaal Al-Mutairi, Mohammed Al-Senafi, Asem AlKhalid, Khalid AlFahad","doi":"10.2118/193747-MS","DOIUrl":"https://doi.org/10.2118/193747-MS","url":null,"abstract":"\u0000 The Kuwait Oil Company's (KOC's) future development plans propose an increase in the production and utilization of groundwater reserves in the northern oil fields, where new groundwater gathering centers are to be constructed for water handling processes. In order to preserve the natural resources of the country, and realizing the fragility of the fresh/brackish/saline coexistence in the groundwater resources of northern Kuwait, the Water Research Center (WRC) of the Kuwait Institute for Scientific Research (KISR) conducted this study on behalf of KOC. The main objective of the project was to design, locate and set a production schedule of groundwater wells to produce 10,000 m3/d with salinity less than 10,000 mg/l for a specific period of time. This study will enhance the potential of utilizing brackish water at the project area while maintaining minimum mixing between brackish and saline groundwaters. To fulfill its objectives, this study conducted data collection followed by designing and constructing several production and observation wells that were used for a program of pumping and recovery tests. During this field work, a campaign of groundwater sampling and water level measurements were conducted. The water samples were analyzed in the appropriate laboratories for physical, chemical, and biological parameters according to international standards. Then, another stage of numerical modelling took place to simulate the movement of saline and brackish waters putting all the newly drilled wells into operation. The results showed that it is possible to extract 10,000 m3/day from the project area with a salinity ranging between 3,500 and 10,000 mg/l indicating brackish water quality. The groundwater in the study area is of sodium chloride and sodium sulphate type, and no organic contamination of groundwater was detected in the study area. However, the study also shows that it is not possible to extract water from certain locations because the salinity will be elevated above the design limit of 10,000 mg/l.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"16 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":"121799009","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":"Seismic Quantitative Interpretation of Heavy oil Reservoir Characterization in North Kuwait","authors":"Z. Ren, A. Al-Rabah, A. Albloushi, M. Freeman","doi":"10.2118/193657-MS","DOIUrl":"https://doi.org/10.2118/193657-MS","url":null,"abstract":"\u0000 Key challenges to seismic imaging of shallow heavy oil recovery in North Kuwait include how to acquire high quality seismic data, and how to carry out seismic inversion and quantitative interpretation (QI) for reservoir characterization. Kuwait Oil Company acquired a high resolution baseline 3D seismic survey over an area of 700m × 700m in January 2017, followed by a six week time-lapse 4D seismic survey, as part of geophysical monitoring project for studying the reservoir and associated steam flood pilot performance. This paper presents the technical methodology and interpretation results of these 3D and 4D seismic surveys.\u0000 Highly pressurized and heated steam injected into a reservoir will move in all directions to drive out in situ heavy oil. It is important to understand where the steam has traveled to, which is controlled by reservoir properties such as formation pressure, porosity, and permeability. Seismic inversion and quantitative Interpretation (QI) are proven tools that can extract information about reservoir properties such as sand probability and porosity, which can be used to estimate steam chamber size, optimize the steam injection strategies and update the geological static modeling.\u0000 The 3D and 4D seismic inversions have confirmed that the data quality meets the QI requirement for such a shallow reservoir. The main outcomes from the pre and post stack inversions are the sand porosity and sand probability. Due to steam injection in the reservoir, seismic amplitude anomalies and time-shifts were observed from seismic slices and time-delay processing, which could be used for estimation of steam injection size. Sand porosity and probability maps were created of the upper zone overlying the lower steamed reservoir, and clearly indicate that steam from the lower reservoir passed through the intervening baffle and spread to the upper zone, which means that the thin baffle in this area could not prevent steam from traveling upwards.\u0000 The key enabler for proper seismic quantitative interpretation is the rock physical modeling, which searches and establishes the relationship between reservoir properties (i.e. sand probability and porosity) and seismic attributes such as P-Impedance and Poisson's Ratio (Vp/Vs). Inputs into the rock modeling process include bulk density logs, compressional and shear sonic logs, and interpreted porosity and clay volume petrophysical logs. A sand probability function is first established using P-impedance and Poisson's Ratio, and then reservoir properties are extracted from the seismic inversion.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 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":"128491142","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 Transient Analysis for Heavy Oil and Low Transmissivity Formations","authors":"R. Alcantara, J. E. Paredes, M. Briones","doi":"10.2118/193669-MS","DOIUrl":"https://doi.org/10.2118/193669-MS","url":null,"abstract":"\u0000 The performance of Pressure Transient Analysis (PTA) in heavy oil and low transmissivity formations is different from the conventional reservoirs, so the main objective of this work is to describe the pressure transient behavior in these low mobility-low transmissivity systems considering their impact on the main issues involved in, such as fluid viscosity, flow capacity, total compressibility and petrophysical properties.\u0000 In this analysis, we present various well tests from many low transmissivity oilfields and some other heavy oil reservoirs in Mexico that produce from distinct depositional environments in sandstones and carbonates at different depths, onshore and offshore, with the objective of comparing and analyzing the pressure transient response with respect to time and the designing and execution of well tests in these types of systems. The main aspects related to the pressure transient behavior in low-mobility and low-transmissivity formations were analyzed, especially for the time required to reach the Infinite Acting Radial Flow regime (IARF) and subsequently, the pseudo-steady or steady state, where some properties are of paramount importance such as fluid viscosity, porosity, permeability, total compressibility, capillary pressure and net pay.\u0000 The evaluation of the critical factors that rule the pressure transient behavior in low-transmissivity formations and heavy oils allows to identify certain patterns in transmissivity variations, determination of mean reservoir pressure, identification of reservoir heterogeneities and the corresponding influence of net pay on carbonates mainly. Furthermore, we suggest a series of recommendations about how to deal with this type of reservoirs when designing, executing and analyzing well tests for a better reservoir characterization through Pressure Transient Analysis (PTA).","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"60 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":"126355462","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":"Design Optimization of Slotted Liner Completions in Cased and Perforated Wells: A Numerical Skin Model","authors":"A. Velayati, Morteza Roostaei, Vahidoddin Fattahpour, Mahdi Mahmoudi, A. Nouri, Ahmad Alkouh, B. Fermaniuk, M. Kyanpour","doi":"10.2118/193670-MS","DOIUrl":"https://doi.org/10.2118/193670-MS","url":null,"abstract":"\u0000 Several parameters affect the skin factor of the cased and perforated (C&P) wells completed with slotted liners. Existing skin factor models for slotted liners account for such factors as the flow convergence, pressure drop and partial production but neglect phenomena such as partial plugging of the screen or near-wellbore permeability alterations during the production. This paper discusses these factors and incorporates them into a skin model using a finite volume simulation.\u0000 The finite volume analysis evaluates the skin factor as a result of pressure drop in the gap between the casing wall and the slotted liner. This skin model accounts for: 1) the perforation density and phasing, 2) slotted liner specifications, and 3) different amount of sand accumulation in the annular space between the casing and the sand screen. A semi-analytical pressure drop model is also linked to the numerical model to incorporate the skin factor due to flow convergence behind the perforations.\u0000 The results of finite volume analysis reveal that a low perforation density would behave close to the open-hole completion for sand-free casing-liner annular space. Conversely, pressure drops were found to be significant for a partially or totally filled space. Additionally, it was found that the optimum completion design occurs if the slotted liner joints are in line with the casing joints. Besides, a partially perforated casing or a partially open sand screen increases the distance fluids have to travel in the annular space and intensifies the skin factor.\u0000 This paper provides skin models derived for vertical and perforated wells completed with slotted liner sand screens using the finite volume simulations. Each part of the model has been verified against existing numerical models in the literature. The model improves the understanding of flow performance of the sand screens and skin factor, which in turn leads to a better design of sand control completions.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 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":"124399602","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":"Experimental Investigation of Steam-Alkali Flooding with Borax: A Case Study on Bati Raman Oil Field","authors":"Wildan Hashim Noori, Murat Cinar, M. Salehian, Ahmad Alkouh","doi":"10.2118/193797-MS","DOIUrl":"https://doi.org/10.2118/193797-MS","url":null,"abstract":"\u0000 Steam injection is one of the well-known thermal recovery processes that has been extensively applied to heavy oil reservoirs. Several efforts have been made to understand theoretical and practical aspects of steam injection and alkali flooding. However, the detailed information about the performance of steam-alkali flooding in field applications has not been deeply addressed yet. In this sense, in order to shed light on the background and applications in this area, this study comparatively investigates the efficiency of different strategies of pure steam injection and cyclic steam-alkali flooding in Bati Raman oil field, Turkey.\u0000 Three experiments were conducted to evaluate the advantage of steam-alkali injection compared to pure steam injection for an 11.6° API Bati Raman crude oil. The steam injection system consists of two reservoirs for water and the alkali solution, an electrical pump, and an electric steam generator. Those three experiments are as follows; conventional pure steam injection, cyclic injection of steam and alkali solution 4.0 wt%, and cyclic injection of steam and alkali solution 8.0 wt%. Steam was injected with the rate of 10 ml/min at 110°C and the system pressure was set to be the atmospheric pressure. The liquid produced from the separators is sampled periodically to determine the oil recovery.\u0000 Observation of sand packs after the experiments indicates the tendency for steam channeling in the vertical direction around the upper thermocouple. Since the upper thermocouple was inserted after the sand packing operation by pressing and rotation, steam could be passed through these channels without entering the all pores in the porous media. The average oil recovery by conventional pure steam injection, steam-alkali solution 4.0 wt% injection, and steam-alkali solution 8.0 wt% are 8%, 3% and 5.5% OOIP (original oil in place), respectively. This indicates that although the oil recovery in conventional pure steam injection was maximum, increasing the alkali concentration in the aqueous solution from 4% to 8% has caused the improvement in the recovery.\u0000 The theoretical and practical information is supported by the experimental examples to evaluate the performance of different steam-alkali flooding strategies with Borax in heavy oil reservoirs of Bati Raman. This study also examines the challenges of steam-alkali flooding in extremely heavy oil reservoirs and explains that the pure steam injection is preferred due the insufficient change in interfacial tension during Borax injection process.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"42 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":"134359034","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 Optimisation of Heavy Oil Wells Using Autonomous Inflow Control Devices","authors":"M. Moradi, M. Konopczynski, I. M. Ismail, I. Oguche","doi":"10.2118/193718-MS","DOIUrl":"https://doi.org/10.2118/193718-MS","url":null,"abstract":"\u0000 The uneven distribution of the production influx from the reservoir into the wellbore has been identified as the main issue in the management of production in heavy oil wells. This occurs due to a drastic difference between the mobility of oil and water i.e. water flows faster than oil in these reservoirs. This can be exacerbated by reservoir heterogeneities resulting in very high water production rate requiring large water treatment facilities which may be limited in offshore developments, resulting in reduced oil production.\u0000 Advanced well completions utilizing Inflow Control Devices (ICDs) and Autonomous Inflow Control Devices (AICDs) have proven to be robust solutions for these problems. Both devices help to enhance the performance of heavy oil wells by delaying the water production, however, AICDs are more capable to reduce the water production and increase oil production even after water breakthrough.\u0000 This paper examines the heavy oil/water production control by ICDs and AICDs and discusses the flow loop test data (single and multiphase flow) to describe the performance of devices for various fluids under downhole conditions. Using an example model, the reasons for the superiority of AICD over ICDs is investigated under different scenarios. An optimisation workflow was used to optimise the well completion design i.e. the size and number of devices plus packer placements and numbers.\u0000 The results of several field applications of AICDs, from retrofitting the existing completions of the wells with very high water cuts (e.g. 98%) to brand new wells in heavy oil fields, will be discussed. AICD completion as a proactive-reactive device was found to be the most efficient completion at controlling the water production from high productive zones or the fractures, compared to the wells equipped with ICDs and other conventional completions while increasing oil production.\u0000 This paper provides insights about inflow control device applications in heavy oil wells and provides a comprehensive guideline on the selection of appropriate completions for the wells in these challenging reservoirs.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"26 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":"115998929","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":"From Exploration to Production in Record Time: A Case Study of Lower Fars Heavy Oil Reservoir in Umm Niqqa Field, Kuwait","authors":"A. Sajer, Haifa Al-Bader, A. Al-Rabah, Sunil Kumar Singh, K. Harami, G. Dillabough, A. Al-Ajmi, A. Al-Ibrahim, M. Ayyavoo, A. Al-Ateeq, Ammar Bosalhah, J. Dashti, F. Al-Qattan, Shoroq Al-Houti, Sudhakar Mushnuri, A. William, L. Arguello, P. Sangani, S. Chakravorty, F. Franco, R. Sahmkow","doi":"10.2118/193688-MS","DOIUrl":"https://doi.org/10.2118/193688-MS","url":null,"abstract":"\u0000 Conventionally discovery to development of a heavy oil reservoir takes very long (Minimum 10-15years). However, significant volatility in the oil prices have required more collaborative workflows and strategies from operators and service companies to optimize cost and maximize efficiency and innovation. We present here a joint service integrated model between an NOC and a service company which was used in the fast track development of an unconventional heavy oil reservoir and resulted in discovery to production in record time.\u0000 A conceptual field development plan was put in place for fast track development of the Lower Fars reservoir in the Umm Niqqa field after drilling and testing 26 exploration wells. The plan consisted of drilling and completing over 80 wells in conjunction with the construction and commissioning of an early production facility (EPF) to handle the sour heavy crude. Given the brief time and the unconventional nature of the reservoir, significant challenges were faced during the execution phase. To address the challenges, an integrated workflow was put in place combining multiple disciplines. The entire project required seamless integration between drilling, characterization, production and surface facility teams for flawless execution. The collaboration resulted in successfully drilling and completing all planned wells in less than 1 year.\u0000 This paper describes the tasks performed during the project for successful execution. It was initiated by a robust assessment of the discovery in terms of OIIP and type of hydrocarbon. It further describes the construction of a fit for purpose field development plan. During the execution phase we explain the challenges faced while drilling deviated wells in soft unconsolidated reservoirs with extremely shallow kick off points. The challenges in logging and evaluating deviated wells to optimize completion strategy are also described. The optimization of testing, completions and artificial lift workflows played a significant role is assessing the dynamic behavior of these reservoirs. The workflows in conjunction with continuous production monitoring and workover planning allowed the minimization of non-productive time (NPT). We further highlight the surface facility designed for such heavy sour crude and the recommendation for future development.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"35 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":"116806537","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":"A Comprehensive Review Heavy Oil Reservoirs, Latest Techniques, Discoveries, Technologies and Applications in the Oil and Gas Industry","authors":"C. Temizel, C. H. Canbaz, M. Tran, Elsayed Abdelfatah, B. Jia, D. Putra, M. Irani, Ahmad Alkouh","doi":"10.2118/193646-MS","DOIUrl":"https://doi.org/10.2118/193646-MS","url":null,"abstract":"Petroleum in general is found in sub-surface reservoir formation amongst pores existent in the formation. For several years due to lack of information regarding production and technology, free-flowing, low viscosity oil has been produced known as conventional crude oil. Fortunately, in recent times, due to advancement of technology, high viscosity with higher Sulphur content-based crude has been produced known as heavy oil. There are also exists significant difference in volatile materials as well as processing techniques used for the two types of crude. (IEA, 2005; Ancheyta et al., 2007). The oil viscosity is a huge problem in regard to heavy oil as both recovery and processing charges increase proportional to Sulphur content and viscosity of the crude.\u0000 Heavy Oil can be used by definition internationally to describe oil with high viscosity (Although the Oxford dictionary might have several variations of the same, within the contents of this paper, we refer to heavy oil as high viscosity crude). Heavy oil generally contains a lower proportion of volatile constituents and larger proportion of high molecular weight constituents as compared to conventional crude oil (often referred to as light oil, we shall describe the characteristics of the types of oil further in the introduction). The heavy oil just doesn't contain a composition of paraffins and asphaltenes but also contains higher traces of wax and resins in its composition. These components have larger molecular structures leading to high melting and pour points. This makes the oil a bad candidate for flow profiles and adversely affects the mobility of the crude. (Speight, 2016). It is crucial to know the heavy oil constitution as it affects: Recovery: Low viscosity and high melting pointsProcessing: Higher Resin, Sulphur and aromatic contentTransportation: Low Viscosity\u0000 These all together impact the economics related to E&P (Exploration and Production) of heavy oil resources. These resources generally have a higher of production associated with them and are one of the first candidates to be affected by reduction of crude prices as seen in 2014 and early 2015. Crude oil can generally be classified into its types by using its API values that are generally obtained through lab testing. Table B1 provides a few popular crude types and their associated API Values.","PeriodicalId":202774,"journal":{"name":"Day 1 Mon, December 10, 2018","volume":"6 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":"124848412","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}