bluuebunny/crossref_metadata_2025_split huggingface dataset:
Comprehensive Multi-Stage Analytical Treatment of Steam-Assisted Gravity Drainage SAGD
Authors: Zargar Zeinab , Ali S. M. 
Published: October 2018

Abstract
A comprehensive analytical model of the Steam-Assisted Gravity Drainage (SAGD) process is developed, encompassing steam chamber rise, sideways expansion, and the confinement phases. Results are validated using experimental and field data.
A new analytical model for predicting steam chamber rise velocity and oil production rate during this period is developed. In this theory, by combining volumetric oil displacement with Darcy oil rate considering the indirect frontal instability effect, the rise velocity, and the steam chamber height are calculated. The model is extended to predict oil production, heat or steam injection rate, heat consumption and Cumulative Steam-Oil Ratio (CSOR) during this phase. The model results show the CSOR decreases, with an increasing oil production rate. The rise velocity increases with an increase in permeability and temperature. Results are validated with experimental and field data.
The sideways steam chamber expansion is treated by a new analytical approach which is called Constant Volumetric Displacement (CVD) where injection rate must be increased continuously for a constant oil rate. At the final stage, adjacent chambers interfere, reducing the effective head for gravity drainage and the heat requirement in this system. For a small well spacing, confinement occurs earlier, heat loss starts decreasing sooner, resulting in a lower CSOR, than for a large spacing.
The above analytical SAGD models including rise, lateral spreading, and confinement phases are combined to obtain the Comprehensive Constant Volumetric Displacement (CCVD) model. The results are validated against experimental and field data. Excellent agreement was obtained with laboratory and field results.
ESP Energy Efficiency Analysis on Western Siberia Fields
Authors: Khabibullin Rinat , Sarapulov Nikolay 
Published: October 2018

Abstract
The paper is devoted to the estimation of energy efficiency of wells equipped with ESP at different operating conditions in Western Siberia. As a measure of energy efficiency, the overall efficiency of the wells equipped with ESPs was used. The ESP efficiency can be defined as the ratio of the useful hydraulic power developed by ESP to electric power consumed by the ESP on the surface. Corporate production monitoring systems have evolved significantly in recent years in Gaspromneft [1]. Large amount of production data has been gathered and processed, including well operation and energy consumption data. It allows to analyze ESP's energy efficiency for each well. This analysis has been focused on comparison of different ESP operating modes – continuously operating mode (COM) – standard ESP working mode and periodic short-term activation (PSA) mode [2]. ESP in PSA mode starts and stops frequently – an average start stop period less that one hour.
The analysis showed that at the current time the information gathered during the monitoring of wells is sufficient to conduct energy audit of the equipment at the level of ESP efficiency evaluation. It makes it possible to identify the dependencies between equipment operation parameters and evaluate the operation efficiency under various operating conditions. Energy efficiency estimation can be used to make decisions for the well stock efficiency improvement. For example, in the course of the analysis, a number of results were revealed: the efficiency in the operation of a well in a periodic short-term activation mode (PSA) in comparison with a continuously operating mode (COM) on a low rate wells is higher by an average of 20%; With the increase in water cut, the EPS's energy efficiency is increasing, both in terms of PSA and COM; The average EPS's energy efficiency decreases with increasing rotating frequency; with an increase in run life, the efficiency of the ESP system is smoothly reduced by an average of 5% in three years, after a gain of 1,300 days, the rate of decrease in efficiency is significantly increased; on COM wells with a motor load of less than 40% efficiency is dramatically reduced, so it is recommended to transfer this fund to the PSA; there is a potential for increasing efficiency and oil production at a low rate wells by using ESP with larger nominal rate in PSA mode and reduced the ratio of operation and accumulation periods. Finally, the efficiency analysis can be used to rank ESP manufacturer by energy efficiency in specific conditions.
SNL Application for Production Logging in Hard-to-Recover Gas Reserves Wells
Authors: Zhurilin Andrey , Dmitruk Vladimir , Mironova Eugenia , Minakhmetova Roza , Aslanyan Irina , Nagimov Vener , Shigapov Ilnur , Aslanyan Arthur 
Published: October 2018

Abstract
Determination of Unit T1-2 (Turonian) flow characteristics in Yuzhno-Russky oil and gas condensate field is a priority area in the development process monitoring. This paper is focused on the informative value of downhole logging surveys conducted for assessment of the reservoir and wellbore flow geometry in the well after hydraulic fracturing. A more detailed consideration of this matter has become possible due to the extensive use of integrated logging suite data during estimation of input parameters for interpretation of pressure transient analysis results.
The difficulty of this task was due to the fact that the extent of the vertical fracture in the Turonian formation was several times larger than the perforation zone and, as a result, estimation of the actual net pay based on the conventional logging suite data was hardly practicable. Besides that, due to poor perforation quality the geometry of fracture flow from the reservoir was affected. In view of this, Spectral Noise Logging technique was applied to estimate the reservoir effective thickness contributing to the flow through the fracture created as a result of the hydraulic fracturing job.
The integrated logging suite supplemented with SNL-HD tool was run at several differential pressures. As a result of SNL-HD and HPT surveys and subsequent flow modelling, valuable information on fracture flow rates was successfully obtained.
The Role of Chemicals Loss in Sandstone Formation in ASP Flooding Enhanced Oil Recovery
Authors: Zhong Huiying , Yang Tingbao , Yin Hongjun , Fu Chunquan , Lu Jun 
Published: October 2018

Abstract
Chemical combination flooding technique especially alkali/surfactant/polymer (ASP) flooding has proven to be an indispensable way to enhance oil recovery (EOR). The progress of this flooding technique in Daqing Oilfield (China) shows that it is promising to keep production from falling and help oil companies make profit in a low-oil-price era. However, the ASP chemicals chromatographic separation and loss in sandstone formation are still the weaknesses in the promotion of ASP flooding.
Laboratory investigations for characterizing the behavior and distinction of chemicals loss in sandstone reservoir with strong base (NaOH) and weak base (Na2CO3) ASP flooding were recently carried out. The experiments were designed to pointedly study the chromatographic separation, and consumption loss behaviors of alkali and surfactant in sandstone reservoirs with ASP flooding. Furthermore, the incremental oil recovery factor in heterogeneous sandstone reservoirs with strong base (NaOH) and weak base (Na2CO3) ASP flooding process was evaluated and compared. The loss rates of chemicals and the permeability damage degree in various experiments were determined respectively, the consumption loss mechanism and influencing factors were discussed, and the formulation composition and slug combination patterns were also optimized. Then, the role of ASP chemicals loss in sandstone formation during ASP combination flooding EOR process was worked out.
The results indicated that the chemicals loss behaviors could be weakened and the chemicals chromatographic separation phenomenon could be alleviated in weak base (Na2CO3) ASP flooding, and the average loss rate of alkali and surfactant could drop 9.61% and 15.67% respectively in heterogeneous sandstone reservoirs comparing to strong base (NaOH) ASP flooding. The profitable EOR effect could also be obtained with weak base (Na2CO3) ASP flooding, and the enhanced oil recovery could still reach 20% or more. Moreover, an approximately 15% reduction in permeability damage rate could be realized in the weak base (Na2CO3) ASP flooding instead of strong base (NaOH) system, and the reservoir flow assurance issues related to chemicals loss behaviors could be addressed. The optimal design of ASP formulation and slug combination pattern could technically and economically achieve high oil recovery in sandstone reservoirs with weak base (Na2CO3) ASP flooding.
The results are beneficial to well understand the chemical combination flooding mechanism and can contribute to the existing knowledge in the chemicals super additive effects during EOR process, and it is also significant to further improve the oil displacement efficiency and reduce the injection cost in heterogeneous sandstone reservoirs with weak base (Na2CO3) ASP flooding process.
Using EPR Technique for Monitoring of ISC Processes and Reservoirs Temperature in Enhanced Oil Recovery
Authors: Mehrabi-Kalajahi Seyedsaeed , Varfolomeev Mikhail , Yuan Chengdong , Pu Wanfen , Rodionov Alexander , Orlinskii Sergei , Wang Ruyan , Gafurov Marat 
Published: October 2018

Abstract
The monitoring of the combustion front in in-situ combustion (ISC) processes is important for the precise control of the air injection to make sure that the combustion process occurred in the expected direction. Our previous study showed that the free-radical signal obtained by Electron Paramagnetic Spectroscopy (EPR) measurements might be applied to determine the direction of combustion front. Therefore, in this study, the feasibility of using EPR as a new and fast technique for monitoring combustion front was further investigated. For this purpose, the oxidation process of different types of crude oils was studied in the low-temperature range from 25 to 180 °C. Free radicals concentration was measured using EPR technique for each sample before and after the isothermal oxidation. The results showed that there is some dependence between the free radicals concentration and temperature. For all the tested crude oils, the concentration of free radicals produced in oxidation process increased with temperature. In a real air injection process, the combustion process inevitably leads to an increase of reservoir temperature. The zone in the moving direction of the combustion front will have a higher temperature than other zones. The increased free-radical concentration can be an indication of the increase of reservoir temperature. Therefore, it is possible to estimate combustion front by analyzing free radicals signals using EPR technique. However, there is no universal relationship being found in this study for different types of crude oils because the sensitivity of EPR technique to oxidation processes strongly depends on the composition of crude oil. That is to say, for each crude oil, we need to find its own dependence between reservoir temperature and free radicals signal for the estimation of the combustion front. Also, it was found that a higher content of asphaltenes resulted in a more significant change of the free radicals concentration with temperature as the asphaltenes can stabilize and increase the lifetime of free radicals due to the presence of π-systems. This implies that the monitoring of the combustion front using EPR technique will be easier and more precise for the oil with a high content of asphaltenes.
Effect of Natural Amphiphiles in Resins on Asphaltene Stability
Authors: Abilova Guzaliya , Milordov Dmitriy , Yakubova Svetlana , Tazeeva Elvira , Yakubov Makhmut 
Published: October 2018

Abstract
The resins of heavy sour crude oils with high vanadium and nickel contents have been investigated. Using original procedure, the concentrates of organonitrogen bases with various compositions and molecular masses have been recovered. The effect of the concentrates on the colloidal stability of the oil to asphaltene precipitation has been studied. Kinetic studies using UV spectroscopy have shown that organonitrogen bases, as well as natural amphiphiles in resins affect asphaltene aggregation and decrease the rate of their precipitation in the solvent/flocculant system.
Novel Well Monitoring Technology Implementation for Multi-Zonal Well in Carbonate Kharyaga Oil Field
Authors: Zoshchenko Oleg , Trushin Yury , Aleshchenko Anton , Mukhametshin Ilkam , Galimzyanov Artem , Nukhaev Marat 
Published: October 2018

Abstract
The Kharyaga oilfield is a large oilfield in terms of its geological resources and a very complex one in terms of its geological characteristics. It is located on the territory of the Nenets Autonomous District. The main production target is carbonate formation which is complex in structure and characterized by a high heterogeneity. Factors such as high-paraffin crude oil, aggressive components in associated petroleum gas (hydrogen sulfide), thick permafrost horizons and harsh weather conditions make the Kharyaga field development technically challenging. The development of the above-mentioned field is characterized by an uneven oil recovery of interlayers and by early water breakthroughs in the highly permeable reservoir sections. Various technologies can be used to monitor well performance.
The article presents the results of the pilot project for the new technology introduction of well performance monitoring. This technology proves successful in cases when traditional industrial geophysical methods of well survey can not be applied for various reasons.
Monitoring of the pilot directional well completed with a cemented casing was carried out using the inflow profiling technology based on chemical intelligent markers. These chemical markers were installed on the well completion elements. Polymer matrices, as well as markers, are placed on the outer side of the casing column in the reservoir intervals with a casing. After casing cementing and perforating through polymer matrices in the producing zone, a large-volume selective acid treatment with 15% hydrochloric acid, inhibitors and diverters was injected. The technology of intelligent inflow tracers is used to monitor the well performance for a long period of its productive time and allows solving the following range of tasks: the inflow distribution by intervals, the calculation of water breakthrough intervals, and the evaluation of the well intervention effectiveness [1].
For the first time in Russia, the directional well was studied using tracers installed behind the production casing. It was followed by cementing, perforation and acid treatment of the bottomhole area.
Multistage Hydrofracturing Efficiency Analysis and Horizontal Well Inflow Profiling Using Spectral Noise Logging Technique
Authors: Andreev Alexey , Kamalov Artur , Zaripov Ansar , Kanyukov Dmitriy , Vyhristyuk Sergei , Yuvashev Albert , Aslanyan Irina , Minakhmetova Roza , Trusov Alexander , Maslennikova Yulia 
Published: October 2018

Abstract
One of the most cost-effective technologies used during the development of hard-to-recover reserves is horizontal drilling with multistage hydraulic fracturing. This paper is dedicated to the assessment of multistage hydraulic fracturing effectiveness in formations with low-permeability and high clay content.
The paper demonstrates how the integrated logging suite supplemented with High-Definition Spectral Noise Logging tool can provide valuable information on the flowing reservoir zones behind the liner and therefore the multistage hydraulic fracturing effectiveness.
Based on the results of logging survey carried out in flowing regime with nitrogen being injected into the well, the hydraulic fracturing job performance was assessed and the inflow intervals were identified. As a result of the multistage hydraulic fracturing job, incremental oil production was achieved. On the basis of an integrated logging survey and field data analysis, the integrity of well completion elements was also checked.
Selection of Optimum Monitoring Technique for Wells with Multistage Hydraulic Fracturing on Priobskoe Oilfiel
Authors: Kolupaev Dmitry , Uchuev Ruslan , Bikkulov Marsel , Matevosov Mikhail , Sheremeev Alexander , Mukhametshin Ilkam , Galimzyanov Artem , Nukhaev Marat 
Published: October 2018

Abstract
With the development of well drilling and completion technologies multistage hydraulic fracturing in horizontal wells has proven to be the most effective method of production stimulation at the Priobskoye field with hard-to-recover oil reserves. At that, evaluation of the efficiency of the multistage hydraulic fracturing and of the inflow from each formation fracture currently remains a complex and vital problem for horizontal wells. Several monitoring methods were practiced at the Priobskoye field in order to select the optimum one from the viewpoint of easy application and the accuracy of the information obtained concerning the productivity of each hydraulic fracture.
The following conventional and contemporary methods of multi-fractured well monitoring have been considered for practising at the field in Western Siberia: conventional production logging tools using coil tubing and distributed temperature survey monitoring technology (DTS) using fiber optic cable, marked proppant and intelligent inflow tracers.
Mechanistic Modeling of Foam Flow Through Porous Media in the Presence of Oil: Review of Foam-Oil Interactions and an Improved Bubble Population-Balance Model
Authors: Ma Kun , Mateen Khalid , Ren Guangwei , Luo Haishan , Bourdarot Gilles , Morel Danielle 
Published: October 2018

Abstract
Modeling foam flow through porous media in the presence of oil is essential for various foam-assisted enhanced oil recovery (EOR) processes. We performed an in-depth literature review of foam-oil interactions and related foam modeling techniques, and demonstrated the feasibility of an improved bubble population-balance model in this paper.
We reviewed both theoretical and experimental aspects of foam-oil interactions and identified the key parameters that control the stability of foam lamellae with oil in porous media. Upon reviewing existing modeling methods for foam flow in the presence of oil, we proposed a unified population-balance model that can simulate foam flow both with and without oil in standard finite-difference reservoir simulators. Steady-state foam apparent viscosity as a function of foam quality was used to evaluate the model performance and sensitivity at various oil saturations and fluid velocities.
Our literature review suggests that, among various potential foam-oil interaction mechanisms, the pseudo-emulsion-film (gas/aqueous/oil asymmetric film) stability has a major impact on the foam-film stability when oil is present. Based on the pseudo-emulsion-film mechanism, we therefore developed a new foam-coalescence function in the population-balance model using the gas-water capillary pressure (Pcgw) in oil-free cases and the pseudo-emulsion capillary pressure (Pcpf) when oil was present. The respective critical values Pcgw * and Pcpf * can be estimated through disjoining pressure measurements. A smooth transition, from no foam destabilization at zero or substantially low oil saturations to no foam beyond a critical oil saturation, was considered for this purpose. The new model was able to handle the extent of the detrimental effect of oil on foam with one adjustable parameter k-2.
This work consolidated various findings of foam-oil interactions based on pseudo-emulsion films in the past through a comprehensive literature survey. We have developed a unified model to simulate foam flow in porous media with and without oil using the mechanistic population-balance approach for the first time. This model can therefore be used in foam EOR simulations both in the oil-bearing zones as well as zones with no oil or residual oil present.
Challenges in the Development of Saline Terrigenous Reservoirs of Eastern Siberia Field
Authors: Levanov Andrey , Ignatyev Nikita , Ostyakov Evgeniy , Vinogradov Igor , Busuek Elena , Cherepkova Anna , Yaschenko Sergey , Schetinina Natalya , Semenov Aleksey , Nesterov Pavel , Musin Roman , Dolgov Igor , Komarov Andrey , Chirgun Aleksandr 
Published: October 2018

Abstract
At present, Russia's oil production in a number of large Eastern Siberia fields (Verkhnechonskoye, Talakanskoye, Yaraktinskoye) has reached or approached its maximum designed levels, therefore, the fields have progressed to the second stage of development or to the beginning of the third stage experiencing production declines. Thus, these fields can be categorized as brownfields.
At the Verkhnechonskoye oil and gas condensate field, for the first time in the history of domestic oil and gas production the geologists came across a highly mineralized productive cross-section with the pore space partially or completely filled with salt. This determined the distinctive development features of the main target - the Verkhnechonsky horizon (Vch) (99.8% of the field's production).
A distinctive feature of this paper is the description of the approaches to the development of the Verkhnechonsky horizon associated scaling formation and control using a wide range of geological and geophysical tools.
The value of the work lies in the summary of lessons learned when managing reserves production and well operation processes at a large Eastern Siberia field, the development of which is complicated by the presence of salts in the pore space, which was the starting point of accumulating the knowledge on salt reservoir development. The experience based on a range of approaches and technical solutions can be applied to similar Eastern Siberia reservoirs with similar geological and physical characteristics.
Characterization of ADOTS Carbogenic Nanoparticle Tracers Before and After Reservoir Injection
Authors: Alqahtani Hassan , Hussain Mohammad Kamal , ALShateeb Hussain , Ellis Erika 
Published: October 2018

Abstract
The main challenge facing any nanoparticle-based reservoir agent stability and transport through hydrocarbon reservoirs under harsh conditions (typically up to 220 kPPM TDS, ~10% divalent cations, 100°C temperature and 3200 psi pressure) without loss or degradation. Therefore, appropriate understanding of the physical and chemical character of candidate systems, e.g. ADOTS fluorescent nano-tracers, is highly needed. Results reported here show that the pre-injected ADOTS diluted in DI water, HPLC water and seawater have exactly the same 450 nm peak under the fluorescence spectrophotometry. However, both pre-injected and filtered post-injected ADOTS samples have also exactly the same peak position. Raman measurements are identical confirming the presence of ADOTS in samples before and after the injection. This improved physical and chemical understanding supports future development of both coatings and novel cores on the ADots platform.