bluuebunny/crossref_metadata_2025_split huggingface dataset:
Numerical Simulation of Polymer Flooding
Authors: Mirsayanova Elina , Ilyasov Ilnur , Cheremisin Alexander , Evseeva Margarita , Cheremisin Alexey 
Published: September 2020

Abstract
Many factors affect the efficiency of polymer flooding, but the key is polymer adsorption on the rock. The analysis of the main methods of experimental elaboration of uncertainties associated with the estimation of adsorption on micromodels is carried out in this article. As part of this work, the following studies were carried out:
review of existing research methods and measurement of adsorption parameter; analysis of relevant uncertainties (adsorption, core, model) and methods for their reduction; carrying out subtle approaches in the study of adsorption on core samples using a filtration unit and measuring the polymer concentration by spectrophotometry; reproduction of the performed experiments on the core on the scale of the micromodel.
The main problems, which are reflected in detail in the course of the experiments, are the complexity of measuring the concentration spectra in the presence of the hydrocarbon phase. This problem was solved by extracting core samples followed by pumping 4 pore volumes of polymer solution of hydrolyzed polyacrylamide Flopaam 3630S.
The main results of the experiments made it possible to clarify the value of dynamic adsorption in the range of permeabilities 450 - 1100 mD for the PK1-3 layers of the East-Messoyakhskoye field. Thus, it was found that the average adsorption value is 338 μg / kg of rock. The results of filtration experiments were modeled in a commercial hydrodynamic simulator, which will allow in the future to assess the effectiveness of polymer flooding for a geological object of field development, to assess polymer losses during its filtration, and to clarify the economic risks associated with the project.
EOR Technology: Surfactant-Polymer Injection to Increase Oil Recovery from Carbonate Reservoir of Kharyaga Oilfield
Authors: Trushin Yuri , Aleshchenko Anton , Arsamakov Mark , Klimenko Alexandra , Molinier Valérie , Jouenne Stephane , Kornilov Alexey , Sansiev George 
Published: September 2020

Abstract
The paper reports on the procedures of selection and evaluation of surfactant-polymer composition to improve the development efficiency of Kharyaga field D3-III carbonate formation. The main goal was to establish an efficient chemical composition that could significantly improve oil recovery factor and are compatible with high salinity formation (up to 170 g/l) and injected water (60-80 g/l) at formation temperature 62°C. Laboratory results include the composition screening and core flood experiments on analogous carbonate cores; the best prospective scheme of injection is validated. A physico-chemical model of oil displacement at negative salinity gradient is validated with technical calculations. Additional laboratory program is currently planned for validation of uncertainty parameters. It includes displacement of oil by surfactant and polymer solutions on Kharyaga field cores and evaluation of dynamic adsorption of chemicals.
Practical Experience in Applying the Technology of Creating a Network of Deep-Penetrating Filtration Channels with the Intensification of the Inflow in the Producing Wells of the Republic Unitary Enterprise Production Association Belorusneft
Authors: Plekhanov Stsiapan Nikolaevich , Moisseyeu Dzianis Vladimirovich 
Published: September 2020

Abstract
The staff of Belorusneft constantly invents, tests and adopts new technologies to develop hard-to-recover oil reserves in the fields of the Pripyat Trough. Conventional reserves are under fast-paced development in this region, while hard-to-recover reserves are not actively developed, although amounting up to 70% of total recoverable petroleum reserves. When targeted penetration of low-permeable intervals and creation of a system of branched deep drainage channels are required, we developed equipment and technology that allow creating a network of deep-penetrating flow channels. The channels run radially in relation to the wellbore with penetration depth of up to 100 m, which can significantly increase the formation fluid flow area toward the wellbore.
A Case Study of Salt-Tolerant Functional Polymer For EOR in Carbonate Reservoirs with Ultra-High Salinity
Authors: Mustafin Aidar Zamilevich , Li Kexing , Varfolomeev Mikhail Alekseevich , Yuan Chengdong , Kadyrov Rail Ilgizarovich , Glukhov Mikhail Sergeevich , Khayrtdinov Ruslan Kamilevich , Pu Wanfen , Sattarov Aidar Ildarovich , Statsenko Evgeny Olegovich 
Published: September 2020

Abstract
In this work, we present a new-type salt-tolerant functional polymer (CBHB) for ultra-high salinity conditions, and investigated its feasibility for polymer flooding in a fractured carbonate reservoir with a salinity of more than 220000 mg/L (Ca2+ + Mg2+ &gt; 10000 mg/L) in Akanskoe oilfield (Tatarstan, Russia). First, the properties of the salt-tolerant functional polymer (CBHB), including solubility, rheological parameters, and long-term stability etc., were evaluated at different salinity conditions and compared with current commercial polymers (total 15 samples). Then, the static and dynamic adsorption were determined using UV-spectroscopy. Finally, regular filtration experiments on a laboratory scale and 4D X-ray tomography core flooding experiments were carried out at reservoir conditions to analyze the microscopic/macroscopic displacement mechanism and efficiency of polymer in real time.
The results showed that only three polymers can be dissolved at 227500 mg/L salinity and 23 °C (reservoir temperature) and give homogenous solution with the viscosity of higher than 100 mPa·s at the polymer concentration of 2000 mg/L. CBHB showed the highest viscosity of 830 mPa·s after aging for 180 days, which means that it has a superior salt tolerance ability. 4D X-ray tomography indicated that polymer displacement front is aligned and even oil in some small pores or caves can be also displaced with almost no oil film left due to a good viscoelasticity of polymer. A high displacement efficiency of 72.94% was achieved. This means that this CBHB polymer not only has the traditional mobility control capacity to increase sweep efficiency, but also have ability to increase displacement efficiency, which makes CBHB polymer have a great potential for EOR in ultra-high salinity reservoirs.
Salt-tolerant functional CBHB polymer for ultra-high salinity of more than 220000 mg/L (Ca2+ + Mg2+ &gt; 10000 mg/L) was developed. It exhibited both high sweep and displacement efficiency due to its functional groups. This will expand the application of polymer flooding for ultra-high salinity reservoirs. Simultaneously, 4D X-ray tomography was innovatively used to precisely investigate the microscopic/macroscopic displacement mechanism and efficiency of polymer flooding.
Smart Bridging Agent - Prevents Formation Damage and Removed with Formation Fluid
Authors: Popov Sergey Viktorovich , Nikitin Pavel Mikhalovich , Udaltsov Denis Aleksandrovich , Ryabtsev Petr Leonidovich 
Published: September 2020

Abstract
Sized calcium carbonate is the most common material used in reservoir drill-in fluids for filter cake deposition. Calcium carbonate has numerous advantages relating to to drilling fluids but also some limitations. Research and field works were performed from mid-2018 to late 2019 to develop and implement a new material that can be used as an efficient alternative to calcium carbonate.
This article describes actual results of the research and field works performed to develop and implement an innovative bridging agent for water-base drilling fluids. The chemical is intended to build a filter cake and has a number of unique properties. The new material enables the solution of certain engineering tasks arising when drilling horizontal wells in a producing formation, in particular, preventing formation damage and increasing development efficiency. The article covers main methods used to elaborate the material and results of pilot works.
Experience of Existing Casing Drilling Technologies in Various Conditions and Search of the New Solutions for Actual Challenges
Authors: Zakirov Artem Yaudatovich , Kartinen Daniil Yurievich , Madyarov Alik Irekovich 
Published: September 2020

Abstract
The components of casing drilling technology are evolving and the application area is expanding. Drilling engineers today have more flexibility than ever before to redesign wells and can combine different technologies, materials and equipment to achieve new records in well construction efficiency. In recent years, PJSC Gazpromneft has been constantly using casing drilling technologies. The increasing complexity of geological conditions and the need to reduce well construction costs lead to more efficient solutions.
The article presents the actual experience of using the following variations of the casing drilling technology:
Non-directional drilling on 426mm casing together with 630mm thermal case at Yamburgskoye field Non-directional drilling on 324mm casing at the Vostochny Section of the Orenburg oil and gas condensate field (VUONGKM) Run in hole with rotation on 245mm casing at VUONGKM. Directional drilling with 245mm casing with a retrievable BHA at VUONGKF.
The use of casing drilling technology has not in all the cases under consideration increased the efficiency of well construction, but at the same time the results obtained allow us to predict an additional increase in the efficiency of the application of these technological solutions.
At the end of the article, a tree of casing drilling technologies was built and segments with development prospects were highlighted.
Innovative Approach for Multilateral Well Completion with TAML 3 Junction Installation in Open Hole
Authors: Erokhin Dmitry Andreyevich , Kashlev Alexander Sergeyevich , Fedotov Andrey Gennadyevich , Pyatkov Evgeny Sergeyevich , Philippov Alexander Viktorovich , Samarin Grigoriy Borisovich , Ivashkin Evgeny Vladimirovich , Solovyev Vladimir Vladimirovich 
Published: September 2020

Abstract
Multilateral well completion technologies are becoming more common throughout the lifecycle of oil and gas fields due to increasing complexity of the reservoirs. Additional lateral drilling tends to increase the contact area with the formation and, as a result, the production rate of a well and allows avoiding the need of design, construction, and maintenance of the surface infrastructure and upper sections of a potential new well. (Muslimov R.H., 2017)
Various factors are considered while designing the well construction: starting from reservoir properties, thermobaric conditions, fluid composition, and up to the surface infrastructure. So, a Multilateral well might be a good solution under certain circumstances. (Shenberger V.M., 2007)
In Russia, the most popular Multilateral completion technology nowadays is level 1 according to TAML1 international classification (with both lateral cased). The noteworthy strengths of the system include its reliability, simple deployment, and proven cost-effectiveness. However, its widespread use is hindered by such constraints as a fundamental limitation associated with the inability to perform following downhole operations (DHL2, HCT3, processing of BHZ4, etc.) in one of the boreholes, which directly affects the effective lifetime of such a well.
Technologies TAML 2 and 3 are the next levels in the international classification describing the construction of a Multilateral well with an exit from previous casing (mainbore). (Bellarby J., 2009) However, the TAML 2 system was not considered for this case due to the lack of mechanical integrity of the junction. The basic TAML 3 system requires both a longer well completion time and additional operations entailing associated risks.
In view of the above, a further development of TAML 1 technology was considered as a solution: Multilateral well completion with TAML 3 junction installation in the open hole preserving its mechanical integrity, with the possibility of selective access to both laterals during following downhole operations without involving additional service equipment.1 TAML - Technology Advancement for Multi-Laterals.
This paper describes the field experience of TAML 3 system deployment in the open hole for the land project, which confirmed the effectiveness of an integrated approach and targeted solutions for further optimization of hydrocarbons production by the example of the Multilateral well construction.
Application of Cemented Multi-Entry Frac Sleeves in Multistage Stimulation: A Case Study
Authors: Stolyarov Sergey , Bagci Suat , Gomez Ricardo , Wright Beau , Yang Junjie 
Published: September 2020

Abstract
Plug and Perf (PnP) completions have been the most widely used multistage hydraulic fracturing methods used in unconventional wells. In a PnP completion, isolation between stages is achieved by setting frac plugs inside the horizontal liner. The number of perforation clusters and perforation holes are designed using limited entry perforating techniques.
While PnP is a proven method, there are also some downsides, particularly when considering the inability to pump plugs due to changes in casing integrity and casing deformation occurring in 20-30% of horizontal wells. Casing damage has been increasingly recognized as a challenge to well integrity in active or child wells during multistage hydraulic fracturing. Casing deformation and reduction in casing inside diameter (ID) prevent the use of PnP operations due to frac plugs being unable to pass through deformed casing.
Cemented multi-entry frac sleeves (MEFS) allow users to imitate the limited entry effect of PnP completions while eliminating the need to deploy large OD frac plugs for each stage. The multiple entry points are activated using various-sized frac balls dropped from the surface as the stimulation treatment is pumped, eliminating the need to rig up and rig down between stages. After fracturing is complete, the frac balls either dissolve or are flowed to surface allowing production to begin immediately—eliminating through-tubing intervention. The multi-entry sleeves use graduated balls and ball seats to open as many as five sleeves per stage with a single frac ball for increased efficiency. Number of clusters and entry points are calculated based on limited entry techniques similar to PnP.
Within this study, two limited entry techniques, PnP and multi-entry sleeve systems, are evaluated using commercial fracture modeling software, and well production modeling to compare the steady-state production between PnP and multi-entry sleeves. Hydraulic fracture modeling is also used to evaluate limited entry perforation design, perf erosion, stress shadowing, and fracture propagation.
Successful Application of High-Speed Negative-Pulse Telemetry with Compressed Data Transmission Aiming to Increase ROP during Horizontal Wells Drilling in Yuzhno Tambeyskoye Gas Condensate Field
Authors: Garipov Andrey , Tur Dmitry , Galimkhanov Aydar , Khalilov Almaz , Yavorsky Alexander , Maltsev Vladimir , Pogurets Valery , Rybalkin Aleksey 
Published: September 2020

Summary
This paper describes the results of efficient cooperation between the Operator, the General Drilling Contractor and the Service Company, who participated in the construction of horizontal wells in Yuzhno-Tambeyskoye gas condensate field.
This document describes an integrated engineering approach to selection of new technical and technological solutions, which safely achieved all the geological tasks while constructing the wells.
The key innovations of real-time data transmission from downhole tools, allowed the quality of the information received to be improved which increased the average rate of penetration (ROP) and reduced the well drilling time. Furthermore, during the project execution a multidisciplinary group of experts developed and successfully implemented a set of measures aimed at reducing flat time.
Comprehensive planning, an efficient organizational structure, effective communication between all the participants and the introduction of new technologies resulted in the safe and successful construction of 6 horizontal wells with 1500 m long horizontal sections delivered 10% ahead of schedule.
Along with the technological progress, it is important to note that during well construction a high level of HSE was achieved with no accidents occurring throughout the entire project.
Plunger Lift System Case Studies in Kazakhstan
Authors: Nurkas Zhassulan , Khabibuyev Khajirakhim 
Published: September 2020

Abstract
Plunger Lift is an efficient method of producing hydrocarbons for a "specific" well conditions. The most important part of the application process is to select the wells with appropriate conditions. Typical Plunger Lift applications are (E. Beauregard, L. Ferguson, 1982):
removal of liquids from gas wells; high gas liquid ratio wells; paraffin and hydrate control; increasing efficiency of gas lift applications (especially for an intermittent gas lift); Further technology studies as well as field pilot projects extended application range of the systems and to the date plungers also being used to (E. Beauregard, S. Morrow, 1989): produce liquids in extremely low pressure reservoirs; produce liquids in retrograde condensate wells; remove water from coal seam methane gas wells; produce liquids in deviated and horizontal wells; prevent downhole freezing problems in high pressure gas wells.
Besides applications listed above, there is also a specific window for a Plunger Lift – well conditions with high gas liquid ratio, where traditional SRP and ESP systems are severely challenged.
Despite the wide and effective application range of the technology and quick payout period, the major obstacle to more widespread utilization of plungers has been a lack of education. This has been a problem not only with operational personnel but engineering and management as well. Key figures on Plunger Lift technology, founders of PCS Ferguson company, Beauregard and Ferguson were mentioning this early in 80-s as the main barrier. Since this period number of Plunger Lift installation is continuously growing in North America and reached up to 4% of total well count, which is today about 30 000 wells.
Nevertheless, in Eastern Hemisphere implementations of plungers are only at the beginning stage.
This paper discusses the latest Plunger Lift applications in Kazakhstan, obtained results, there are also some operational guidelines on more effective implementation ways.
Effectiveness of Implementing ESP Life Cycle System in Salym Petroleum Development
Authors: Musorina Anastasia Dmitrievna , Safonov Viktor Nikolaevich , Ishimbaev Grigory Sergeevich 
Published: September 2020

Abstract
Fluctuations of macro-economic indicators, global financial crises and supply excess over demand at the oil market have historically been the reasons for the oil industry profitability decline. On the one hand, it certainly influenced the revision and reduction of investment projects, and on the other hand, it more than ever reflected the importance of improving oil production efficiency and reducing its cost. Salym Petroleum Development (SPD), as a producing company, has always paid considerable attention to improving the efficiency of oil and gas production processes, the reliability of running equipment and the quality of process operations. In 2016, SPD changed its systematic approach to DPE (down-hole pumping equipment) operation and oil production optimization by implementing the "ESP Life Cycle" system, which involves a detailed review and improvement of each stage of the ESP life cycle (Figure 1).
Determination and Forecast of Formation Pressure, Productivity and Reservoir Properties Based on Well Production Analysis Using Kappa Topaze Software Without Shutdown of Wells Equipped with Downhole Pressure Gauges and Telemetry Systems for LUKOIL-PERM LLC Fields
Authors: Kuznetsova Elena Aleksandrovna , Shilov Aleksandr Vladimirovich , Nikulin Sergei Evgenyevich , Chernykh Irina Aleksandrovna 
Published: September 2020

Abstract
Flow testing (FT) is an integral part of any field development. Testing results are used to plan well interventions, analyze the current field development state and make up project documents. However, this testing implies significant financial losses caused by incomplete oil recovery due to time-taking well shut-ins for up to several months, which is especially relevant to horizontal wellbores, fractured wells, low-permeability reservoirs.
The production analysis method described in this article allows assessing the same set of reservoir and well parameters as that used for the traditional flow testing, but without oil production losses. The method was tested on 95 wells of the LUKOIL-PERM LLC fields. In order to assess the credibility of the obtained reservoir parameters, the authors made a comparison with the pressure build-up (PBU) interpretation results. The good convergence for the key reservoir properties revealed for most wells testifies that the method is promising as a supplement to transient flow testing.
The authors developed criteria and determined an area of application for this type of testing for Owner's fields after studying specialized plots, identifying the dependence of results on the quality of input data, as well as assessing the forecast capabilities of the production analysis method.