bluuebunny/crossref_metadata_2025_split huggingface dataset:
Downhole Receiver Based Technology for Geophysical Monitoring of Super-Viscous Oil Deposits Development by Steam Injection
Authors: Sudakov Vladislav , Khasanov Damir , Stepanov Andrey , Nurgaliev Danis , Usmanov Sergey , Amerkhanov Marat , Lyabipov Marat 
Published: December 2018

Abstract
The authors consider the technology for monitoring of shallow super-viscous oil (SVO) deposit development process aimed to determine the heated zones distribution corresponding to the drainage areas to enhance the efficiency of development process based on steam injection. The main objective of the work is to develop the monitoring approach based on downhole receivers and interpret the results of surface geophysical survey conducted with the use of downhole receiver tools.
The downhole monitoring tools (receivers) are used to improve the sensitivity of the method and to decrease the environmental influence. Each tool includes 3 geophones located in metal case and is connected with the surface by wireline. The tools are set in the bottom hole of evaluation wells and the wells are abandoned. There are several factors influencing the seismic wave velocities (temperature, pressure, saturation etc). To provide more adequate interpretation geophysical methods with different nature are were to use in complex. The surface monitoring methods considered include shallow seismic prospecting and electrical prospecting.
The results of periodical geophysical investigation are the maps of seismic wave propagation delay from surface source to the downhole receivers, electrode resistivity maps and interwell resistivity maps for different moments of time.
Basing on the change of seismic wave ray velocity the heated regions are identified and the type of fluid saturation estimated with the use of resistivity mapping. The results obtained were used for the development planning including the injection pipe positioning.
The interpretation results in terms of heated zones location obtained in the area of study was compared with the direct temperature measurements by periodical optical fiber thermometry conducted in horizontal producer wells.
The possibility of steam injection process monitoring by surface geophysics with downhole receiver tools is shown basing on the real field case of shallow super-viscous oil deposit.
The relations between geophysical fields considered and reservoir characteristics (temperature, saturation, pressure) are discussed.
The work was supported by the Ministry of Science and Higher Education of the Russian Federation (project No. 02.G25.31.0170) and by the subsidy allocated to Kazan Federal University as part of the state program for increasing its competitiveness among the world's leading centers of science and education.
New Technologies Enhance Efficiency of Hydraulic Fracturing Stimulation in Heavy Oil Reservoirs
Authors: Cai Bo , Duan Guifu , He Chunming , Gao Yuebin , Li Yang , Xu Zhihe , Jiang Wei 
Published: December 2018

Abstract
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.
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.
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.
Implementation of Well Performance Management System WPMS Leads to Significant Cost, Time Reduction
Authors: Al-Barazi Naser , Elekhteiar Hazem Mohamed , Swapnil Bhamare , Sujit Bhatevara 
Published: December 2018

Abstract
A Multiwell drilling campaign was undertaken to enhance the production of a heavy oil field. Well deliverability within the target time was very difficult, as the wells were designed with a challenging profile with a DLS of 13° per 100ft at a very shallow MD of +/- 1600ft. Immediate Optimization of the entire Drilling campaign was required from the inititation of the project to meet the production requirements. Monitoring and optimization of drilling performance was required through a systematic and unique improvement cycle divided into phase's viz. PLAN, DO, CHECK and IMPROVE. As all the offset wells were vertical, there was no data available for benchmarking initial drilling performances of these challenging well profiles. Once a few wells were drilled, the data was analyzed for benchmarking, technical shortcomings were clearly identified and the lessons learnt were implemented in the next planning stage. Risk assessment was done for every section based on the Non Productive Time data analysis of the few initial wells. Monitoring performances and applying corrective measures for improvement resulted in complete Optimization of the Drilling Campaign. Once performance baselines were established, an immediate impact of 10% was achieved in the subsequent batch of wells. Non Productive time and Invisible Loss time were reduced by a significant amount. Good performances were appreciated at the end of the project. Drilling Optimization lead to reduction in average drilling days per well from 12 days to around 8 days. This resulted in completion of the entire drilling campaign safely, well ahead of target time, saving not only rig operating cost, but also enabling early production. This also resulted in reduction of overall cost per foot of the wells drilled in the campaign. Effective communication of all the lessons learnt and benchmark performances to the grass root level by organizing large scale workshop on the rig site, involving all the Drilling Engineers, rig contractor crew and service partners. Technical discussions with all service partners’ together, leading to implementation of lessons learnt while drilling a challenging profile of 13°/ft DLS well.
Pressure Transient Analysis for Heavy Oil and Low Transmissivity Formations
Authors: Alcantara Ricardo , Paredes Jorge Enrique , Briones Mario 
Published: December 2018

Abstract
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.
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.
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).
Strategic Competencies for Non-Conventional Heavy and Extra Heavy Oil Fields: Identification, Definition and Measurement
Authors: Ortiz-Volcan Jose Luis , Al-Khamees Waleed , Ahmed Khalid 
Published: December 2018

Abstract
The ability to deliver oil production capacity by 2040 will highly depend on availability of strategic competencies to support the timely and reliably development of non-conventional oil fields that require intensive application of improved oil recovery technologies throughout all stages of the field life cycle. This paper presents a practical approach for identification, definition and measurement of strategic competencies required to develop and produce non-conventional heavy and extra heavy oil assets.
An activity-based strategic competency model was developed considering a typical heavy oil project with 94 activities organized in 7 field life cycle phases: 1) Data acquisition for uncertainty reduction, 2) static modeling, 3) dynamic modeling, 4) field development planning, 5) well and facilities engineering, 6) execution and 7) operations and monitoring. Each phase undergoes activities with relative duration followed by decision gates with relative contribution of technical disciplines grouped in functions. Ranges of weights in percentages and duration in months are calibrated using analog fields or typical projects, as input for stochastic modeling to account for uncertainty.
The application to non-conventional heavy and extra heavy oil fields in Kuwait, allowed identification of 55 technical competencies classified under 12 functional competency groups under four major categories: Subsurface-reservoir, subsurface-well, surface facilities & production operations and asset integration & planning. These technical competencies were mapped with three scenarios for intensity of work: minimum (low), medium (likely) and maximum (full) to conduct critical activities on annual basis during the 7 phases of the heavy oil field life cycle. Local experience in Kuwait as well as worldwide analog for heavy oil development provided foundation to validate strategic competencies and to calibrate the model, and then used as strategic workforce planning tool to support the preparation of heavy oil project proposals. The model also allowed for stochastic modeling of person-hours and total cost of the work force, including the associated competency development and assurance costs, which shall be included in both Capital and Operational Expenditures as part of the economic model for evaluation of heavy oil development opportunities.
The presented approach is a practical project-planning tool for mapping all required competencies and intensity of work force for more reliable Front End Loading (definition) of heavy oil field development business plans or for existing fields undergoing operations. The phased model allows easier planning and flexibility to conduct exercises with estimates of work force for a range of potential business scenarios.
Refining Technology and Processing Developments
Authors: Al-Azemi Hamed 
Published: December 2018

Abstract
Heavy crude oil production in world over is increasing gradually, resulting in higher atmospheric residue yield. Main product qualities such as high sulfur content, metals (Ni, V) & Conradson Carbon Residue (CCR) content in heavy crude & its distillation products pose challenges to refinery operation.
Kuwait Integrated Petroleum Industries Company (KIPIC) has Al-Zour Refinery (ZOR) which is designed to process a wide range of crudes; 30° to 14° API such as Kuwait Export Crude (KEC), Kuwait Heavy Crude (KHC), Eocene and Lower Fars for supplying LSFO to power plants and marketing high-quality products) for export as per international specifications. ZOR Complex has the world's largest Atmospheric Residue Desulfurization (ARD) units, which is the heart of Al-Zour Refinery. ZOR Project today is in advanced stage of Detailed Engineering, Procurement and Construction (EPC) phase.
This paper addresses the features and challenges experienced during the design of residue hydro-treating facilities for heavy oil processing in ZOR and especially ARD with respect to environmental and economic considerations. The road map of this paper starts by apprising its preliminary studies (external agencies studies & licensor pilot test), and challenges in developing a responsive design changes in the project in line with strategy of crude production plan to meet the objective of processing different types of heavy crude in KUWAIT.
The Application of CO2 Assisted Cyclic Steam Stimulation
Authors: Liu Ning , Zhang Yan , Wang Guodong , Xin Kunlie , Wang Xiaodong , Zhao Zihan , Zhao Fan , Zhang Jing 
Published: December 2018

Abstract
D block is a heavy oil reservoir that was first developed in 1997 with the method of Cyclic Steam Stimulation (CSS). After nearly 20 years’ development, several technical challenges have shown: the reservoir pressure decreased from 7.4MPa to 2.9MPa, and the Steam Oil Ratio (SOR) increase from 2.86 to 3.56. As a result, the traditional CSS method seems to be uneconomic.
In view of the problems shown above, CO2 assisted CSS was tested in this oilfield and has shown great success as follow: The steam injection pressure increased from 5.7 MPa to 6.9 MPa and the SOR decreased from 3.45 to 2.86. Besides the underground success, CO2 was separated from the associated gas and then reinjected into the reservoir. This process can reduce the emission of CO2 so that it is both a economic and green method. In addition, according to the field performance, this paper seeks to establish a better understanding of the possible mechanisms involved in the CO2 assisted CSS.
Loss Circulation Materials Testing Methods: Literature Review
Authors: Al-Arfaj Mohammed , Amanullah Md. , Al-Ouhali Raed 
Published: December 2018

Abstract
Loss of circulation is a major source of non-productive time (NPT) in the drilling operations worldwide. Different types of loss circulation materials (LCM) have been developed and used to minimize mud losses and mitigate the associated problems. Before a new type of LCM is deployed in the field, it needs to go under extensive laboratory testing with simulated downhole conditions to measure its performance. Therefore, a number of LCM testing methods have been introduced to test the effectiveness of those materials with the ability to have a high-temperature high-pressure (HTHP) environment.
Review of published information indicates different research studies with emphasis on various critical factors to come up with different testing methods and apparatus to evaluate the performance of LCM's under a set of experimental conditions. Some testing methods have the capability of doing the testing at high temperature and/or high pressure while others are built of transparent materials and have the advantage of allowing the researcher to monitor and visualize the invasion depth, fluid level drop, deposited thickness, plugging mechanism…etc. In addition, depending on the size of the apparatus and simulated openings, which frequently are slotted disks, each apparatus has a maximum limit in terms of the particle size of LCM it can handle. Practical considerations should be taken into account when designing a testing cell such as the size of the cell, simplicity and portability, data acquisition system, etc. Large testing cells require large quantities of LCM pills mixed with drilling fluids and, therefore, requiring to mix large quantities of drilling fluids for each test run. Hence, this test should be conducted for selective studies of LCM performance. Cleaning of the test apparatus after each test is an important factor as well to be considered in the design to make it more user-friendly and avoid any detrimental impact on subsequent test results.
Implementation and Assessment of Production Optimization in a Steamflood Using Machine-Learning Assisted Modeling
Authors: Sarma Pallav , Lawrence Ken , Zhao Yong , Kyriacou Stylianos , Saks Delon 
Published: December 2018

Abstract
Data Physics reservoir modeling and optimization was described in detail in a prior paper (SPE-185507) and can be conceptualized as a physics-based model augmented by machine learning. In brief, the production, injection, temperature, steam quality, completion and other engineering data from an active steamflood are continuously assimilated into the Data Physics model using an Ensemble Kalman Filter (EnKF), which is then used to optimize steam injection rates to maximize/minimize multiple objectives such as net present value (NPV), injection cost etc. using large scale evolutionary optimization algorithms. The solutions are low-order and continuous scale, rather than discretized, therefore modeling, forecasting and optimization are significantly faster than traditional simulation.
The goal of steamflood modeling and optimization is to determine the optimal spatial and temporal distribution of steam injection that will maximize future recovery and/or field economics. Accurately modeling thermodynamic and fluid flow mechanisms in the wellbore, reservoir layers, and overburden can be prohibitively resource-intensive for operators who instead often default to simple decline curve analysis and operational rules of thumb. Data Physics allows operators to leverage readily-available field data to infer reservoir dynamics from first principles.
This paper updates the case study from the previous paper and presents the results of actual implementation of an optimized steam injection plan based on the Data Physics framework. The case study is from a shallow, heavy oil field in the San Joaquin Basin of California, and demonstrates the practical application of Data Physics modeling and the ability to explore future injection plans. The model of the field was fit to historical data in June 2017, after which an optimization was performed and a forward-looking production forecast was established associated with a target plan chosen by the operator. This plan was then implemented in the field over the last year. This paper provides a comparison between the field implementation and the model prediction, which allows for model validation and highlights opportunities for further improvement.
For completeness, this paper includes a summary of the modeling and optimization problem and results from the previous paper.
Generation of BFW Using Bacteria Containing Reject Streams from Municipality Sewage Plant - Kuwait and Related Challenges to Meet Set BFW Spec
Authors: Ghouti Rachid , Kuijvenhoven Cornelis , Al-Anzi Ealian H , Al-Hasan Meshari M 
Published: December 2018

Abstract
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.
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.
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.
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.