bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Combination of Ridge and Conical Elements is a New Approach for Drilling Out Hard Carbonates and Sandstones Without Drop in ROP
Authors: Lomov Alexander , James Biju , Konysbekuly Galymzhan , Gumich Dmitrii , Rasulov Ruslan 
Published: October 2018

Abstract
Designing and developing competitive tools for use in the oil and gas industry to meet the high-demand market requires years of experience and a high-level knowledge base. In today’s drilling environment, innovations in bit technologies play an increasingly important role to improve overall drilling performance and reduce drilling time. Cylindrical cutters had their own limitations and restricted the drilling industry from advancing the operations performance to the next level. 3D-shaped cutters were developed to provide maximum drilling efficiency in the most challenging applications by mitigating cutting structure damage and improving its technical limits. The invention of the 3D polycrystalline diamond cutter (PDC) is helping operators to drill wells faster by improving rate of penetration (ROP) and reducing in-out trips.
The combination of ridged diamond element (RDE) and conical diamond element (CDE) on bits is a new method for drilling formations. These bits improve drilling ROP by maximizing the shape of the PDC cutters. This combination also improves cutter durability, which in turn, enhances bit performance and drilling efficiency. Bits equipped with these 3D cutters require less mechanical specific energy during drilling compared with bits having conventional cylindrical cutters, which helps to reduce shock and vibrations and weight on bit required to drill hard formations.
Field data have proved, beyond any doubt, the benefits from using the combination of 3D PDC cutters in drilling hard formations. These cutters, depending on the shape, are able to improve ROP and durability, and by placing them in the right position on the bit, can improve the overall durability of the bit.
Multiple field tests were conducted in various applications with customers in Russia. The results clearly showed that the combination of these unique 3D cutters helped operators achieve a step change in performance by improving ROP and depth drilled. In some cases, operators were able to drill an entire section using bits equipped with 3D cutter combinations, whereas traditionally more than one bit was used to complete the section. This paper will present the advantages provided by 3D cutters and by implementing a combination of CDE and RDE 3D elements in challenging applications in Russia, in addition to performance benchmarks achieved using this unique combination of 3D cutter combinations.
Integrated Approach to Real-Time Drilling Optimization Based on Methods of Geosteering, Petrophysics and Geomechanics
Authors: Mylnikov Danila , Tatur Olga , Sabirov Airat , Brazlauskas Anton , Petrakov Uriy , Sobolev Alexey , Sigarev Sergei , Kustarev Dmitry , Yakovlev Konstantin 
Published: October 2018

Abstract
The objective of this work was to drill a horizontal well in the Bazhen formation (Western Siberia, Severo-Demyanskoye field) in order to achieve the maximum possible efficiency both from technological and economical points of view. To solve the task, it was decided to apply a integrated approach to drilling support: synchronously use the methods of geosteering, the results of geomechanical modeling and evaluation of the reservoir properties during the drilling process. The experience of drilling support accumulated by the company at the beginning of the work demonstrated that the coordinated use of the three disciplines leads to an increase in the efficiency of the well construction process.
Pre-drill geomechanical models of the geological interval of interest were constructed for the target well, and also reservoir properties were evaluated. The wellbore stability analysis is carried out and intervals with high risks of destruction of a breed on walls of a chink are revealed. To minimize risks, recommendations were given on the technological parameters of the well construction: mud weight, casing shoe depth, etc.
Based on the actually measured rock properties, the petrophysical characteristics of the formation were evaluated. Geosteering methods were used to correct the trajectory in real time for the most efficient well placement in the target interval with the best reservoir properties. Every time the trajectory was changed, the geomechanical model was rebuilt, demonstrating an updated risk map. As a result, the well trajectory was adjusted taking into account minimization of unstable borehole risks.
Multiphase Flow Metering-A Case Study from Badra Oil Field
Authors: Hosgor Fatma Bahar , Toral Haluk , Cai Shiqian , Dudich Maksim , Ilyassov Arman , Budarin Gennadiy , Malyavko Alexander 
Published: October 2018

Abstract
This paper presents the full cycle project experience for the implementation of multiphase flow meters at the Badra Oil field at the well head and production lines, including a discussion of the design and selection criteria and a detailed description of flow loop proving, commissioning and on-going validation and tune up procedures. In addition, results of further research based on field data is presented including a study of the potential of neural nets for transfer learning and automated malfunction detection.
Completion Design Optimization for Production Wells on Badra Oilfield
Authors: Kuzovkin Ilia 
Published: October 2018

Abstract
Badra oilfield started production in 2014.
After some time from the beginning of the field operation, several troubles manifested itself.
Analysis of tubing performance detected clear indication of gas slippage effect on low rate wells and tubing choking effect on high rate wells. Several issues with well integrity also lead to re-assessment of completion design.
During selection of new tubing size and completion equipment, factors like production rate, reservoir depletion, GOR, Flowing buttonhole pressure, wellhead pressure and temperature were taken into account.
In addition to that, possible well interventions and expected tubing loads were considered.
As a result three groups of wells have been identified - low, high and medium production rates in terms of Badra field with new completion concept for each group.
New completion design was selected and implemented on several wells and showed its better performance for new production conditions.
Moreover, selected production tubing diameter and completion components has lower cost and allows any well interventions that might be planned on the field. In addition to that, new completion string can last longer due to its higher corrosion allowance.
Application of the Evolutionary Algorithm for Creating Advanced Technologies for the Beneficial Use of Gas in Order to Increase the Efficiency and Reliability of the Operation of the Technological Equipment
Authors: Vlasov Artem , Fedorenko Valery , Yakovlev Vitaly 
Published: October 2018

Abstract
The work is devoted to the estimation of the contribution of the achievements of science and technology realized in the technological equipment for the use of gas aimed at increasing the reliability and efficiency of solutions for field development.
Increasing the efficiency and reliability of gas utilization systems is possible through the integration of technological solutions based on combined physical effects into their composition. Integration into old or newly created equipment of scientific and technical discoveries allows creating flexible technological solutions. Reducing the mass-dimensional characteristics of equipment for the use of gas is achieved through the use of modern lightweight materials and structures, and the integration of equipment into single block-modular construction-variable structures. The design of the building-alterable elements of new products in full factory readiness reduces the construction and installation costs by 10-15%, allows to reduce the occupied area of installations by 5 times
The evolutionary algorithm for creating advanced technologies for the useful use of gas is based on the integration of scientific and technological discoveries into old or newly created equipment.
The solutions developed by the algorithm include the latest achievements of science and technology. Such solutions for gas utilization systems allow: to reduce costs for CAPEX and OPEX up to 5-10%, increase efficiency of electric installation drive (~ 10%), reduce oil carryover with gas up to 3-5%, return additional volume of liquid hydrocarbons (110- 150 g / m3) into commercial oil.
Criteria of Gas and Gas-Condensate Wells Production Co-Processing Using a Single Processing Train at the Gas Processing Plant
Authors: Nerodenko Dmitriy , Kudrin Pavel 
Published: October 2018

Abstract
A new approach is proposed to choose the option for gathering and processing of hydrocarbons in the commingled development of natural gas fields with a low potential content of C3+ hydrocarbons (for this article purpose, they are hydrocarbons of Aptian-Albian-Cenomanian deposits with a potential content of C3+ hydrocarbons up to 3 g/m3) (hereinafter dry gas) and natural gas with a high content of C3+ hydrocarbons (for this article purpose, it means hydrocarbons of Neocomian, Achimov and Jurassic deposits with a potential content of C3+ hydrocarbons of more than 100 g/m3) (hereinafter wet gas).
The option for commingled gathering and processing of hydrocarbons using shared process facilities by the method of a low temperature separation (LTS) is under consideration as well as the option for the separate arrangement for hydrocarbons with a different content of condensate.
The approach novelty is to use available calculation results for basic criteria that determine technical and economic efficiency of choosing a particular option for gathering and processing of hydrocarbons.
The option choice for hydrocarbon processing is determined by economic efficiency, which in turn depends on the amount of condensate losses with sales gas in the option for commingled gathering and processing of hydrocarbons. The loss of condensate is meant the volume of C3+ hydrocarbons converted to a gaseous state in the process of hydrocarbons processing as a result of mixing of dry and wet gases. In this paper, the relationship of condensate losses with sales gas when changing different criteria affecting its amount is established and illustrated.
The road map to select the option for gathering and processing of hydrocarbons is developed and presented in the form of successive calculations and analytical stages that allow researchers to quickly analyze each particular development option and take a decision on the choice of the most profitable option for processing of dry gas or reject a knowingly loss-making option.
The application of this approach will enable to significantly reduce time losses at "Assessment" and "Choice" stages and not to require services of highly qualified personnel for material balance calculations of the process facility.
Determination of Operating Efficiency of Sucker-Rod Pumping Units of Different Design in Horizontal Wells
Authors: Kitapov Ildar , Gilfanov Rustam 
Published: October 2018

Abstract
The objective of this study was to develop a sucker-rod pumping unit with a special design and to test it in the given conditions. Such conditions are the wells with a horizontal well bore or controlled directional sidetrack, operated with sucker-rod pumping units within the bore curvature ranges close to 90°.
The tasks of this development were the following: operation of horizontal wells with the maximum bottom hole pressure reduction; increase in the drainage speed; increase in the volume efficiency of the sucker-rod pumping units when operated in horizontal wells in fields in their later stage of development; decrease in the impact of gas on sucker-rod pumping unit operating efficiency.
Complications in operation of wells with horizontal well bores or controlled directional sidetracks are following: restricted use of different types of pumps in lifting operations; the main type is operation of sucker-rod pumping units in the curvature ranges that do not exceed 42°. If exceeded, this value leads to reduction of pump fillage by 14% [1] or complete pump starvation due to the valve operating with delay when the valve settles into its seat, which leads to leakages through valve foam.
Study of the Submersible Sand Separator in the Field of Centrifugal Forces for Increasing the Artificial Lift Efficiency
Authors: Nikonov Evgeny , Goridko Kirill , Verbitsky Vladimir 
Published: October 2018

Abstract
High mechanical impurities content in production fluid is one of the main causes high mechanical impurities content in production fluid. In the field practice there are many technologies to minimize solid phase flow from reservoir to the bottomhole and various technique units to protect submersible pumping equipment. However, currently there is no detailed study of technical and technological efficiency parameters.
Different methods and technologies to solve the problems of oil (water) well production, complicated by solid phase flow, are used. In this paper the study results of the submersible sand centrifugal separation for artificial lift are presented, with consideration of the abnormal well conditions.
In Gubkin University at Reservoir and Production Petroleum Engineering Department (RPPED) experimental stand unit to complex study of submersible sand separator (model “PSM") with hydraulic gate was constructed. Experimental stand unit allows determining submersible sand separator (SSS) efficiency. The submersible sand separator experimental stand studies have been conducted on model mixtures “water – solid particles (suspended solids content up to below 2 g/l)" and “water – gas (flow gas content up to 60%) – solid particles". The influence patterns of suspended solids content, inlet flow gas content and granulometric on “PSM" separation efficiency are determined.
The “PSM" efficiency was experimentally confirmed and the separation coefficient values were obtained, which exceeded the performance of the similar devices. The workflow to select candidate-wells for this protective device application was developed. A new technological scheme to lift separated impurities bypassing submersible pumping equipment on the day surface is proposed.
Phase Transitions in the Preparation of Oil Extracted from Oil Rims
Authors: Ivanov Sergei 
Published: October 2018

Abstract
Most of the undeveloped reserves in Russia are hard to recover (TRIZ) and are poorly understood (over 65% of undeveloped reserves are classified as C2 reserves) [1]. Hard-to-recover reserves (TRIZ) – reserves of deposits (fields, objects of development) or parts of the Deposit, characterized by relatively unfavorable geological conditions for the extraction of oil and (or) its physical properties, the development of which by existing technologies in the current tax system is economically inefficient [2].
Hard-to-recover reserves include: Deposits with high-viscosity oils;Depleted (depleted) deposits;Thin oil rims;Deposits which are remote from the infrastructure;Deposits with low-permeability reservoirs;Unconventional reserves: Bazhenov, Abalak, Hadum and domanik formation;Gas hydrate deposits.
The main feature of the oil rims is a small reservoir capacity: from 2-3 to 15 m above the oil layer located a much bigger gas cap, which is in a hydrodynamic connection with the oil. The development of these deposits is due to the following characteristics: –full hydrodynamic connection of the oil layer with the gas cap and the aquifer and mobility of oil and gas and water contacts in the development of the Deposit;–uniform distribution of reservoir energy over the oil and gas area, equal to the initial reservoir pressure and oil saturation pressure;–relatively close location to the faces of oil and gas wells and water-oil contacts in the drainage of oil rims;–instability of the process of oil displacement by gas, leading to a rapid gas breakthrough to the bottoms of production wells, increase of the gas factor of the produced fluid and ultimately to a significant loss of reservoir energy and a decrease in oil recovery;–the possibility of retrograde condensation due to the pressure reduction in the gas-saturated zone of the formation, which predetermines the formation losses of condensate;–maintaining reservoir pressure (PPD) is ineffective and is not able to keep the gas cap in its original position.
As a result, oil recovery does not exceed 10% of the initial reserves [3].
A Case Study of an Efficient and Cost-Saving ICD Completion Design to Manage Production Flow Heterogeneity in Filanovskogo Russia Field
Authors: Osunjaye Gbenga , Abdelfattah Tarik , Snitkoff Joshua , Absalyamov Roman , Golenkin Mikhail , Zavyalov Alexander , Stolboushkin Eugene , Rymarenko Konstantin , Nukhaev Marat 
Published: October 2018

Abstract
Typical wells in the Filanovskogo field are in a multi-zone reservoir with heterogeneous production flow profiles. The use of inflow control devices (ICD) in conjunction with zonal isolation packers, though successful, continues to evolve to improve overall ICD performance. However, in a contemporary cost-driven oil and gas market, persistent innovation has resulted in ICD performance improvement, and it has introduced changes that yield cost-effective deployment approaches, as evident in this case for Filanovskogo field.
This paper details the inherent production challenges posed by the heterogeneity of Filanovskogo reservoir flow profiles. Analysis of the flow profiles facilitated an optimal inflow control modeling that efficiently balanced the production inflow across the various zones and provided means to restrict water inflow selectively. The ICD modeling yielded a solution that assured an improvement in oil recovery from the reservoir. In addition to the sought-after production benefit, the completion design incorporated equipment that collectively reduced operation sequence.
The executed completion design features installation of nozzle-type ICDs fitted with premium screens and integral screen isolation valves. An in-depth look into the operational steps is provided, along with a comprehensive review of the technologies that facilitated this streamlined execution. This review includes a technical overview of the integral sliding choke sleeve of the ICD that can be actuated open/close in the future to manage water ingress. The outcome of this completion design is a solution that saves wellsite operating hours, allows execution of multiple steps simultaneously, depicts production flow balance, and ultimately delivers an enhanced oil production lifespan.
This completion design has leveraged the successes from industry best practices, particularly in ICD applications, to devise a region-specific solution that is relevant in today's cash-conservative market.
Standalone Sand Control Failure: Review of Slotted Liner, Wire Wrap Screen, and Premium Mesh Screen Failure Mechanism
Authors: Mahmoudi Mahdi , Roostaei Morteza , Fattahpour Vahidoddin , Sutton Colby , Fermaniuk Brent , Zhu Da , Jung Heeseok , Li Jiankuan , Sun Chong , Gong Lu , Shuang Shuo , Qiu Xiaoyong , Zeng Hongbo , Luo Jing-Li 
Published: October 2018

Abstract
Standalone screen has been widely used as sand control solution in oil industries for over a century. Screen plugging and impairments by formation fines, scaling and corrosion cost oil and gas industry significant amount of resources. This study presents a detailed study on the corrosion and plugging of slotted liner, wire wrap screen and mesh screen samples extracted from the field to better understand some of the mechanisms for these poor field performances.
Three types of standalone screen were received from operating wells to study the failure mechanism of the screen and provide recommendations for recompletion. A thorough visual inspection of all screens was performed and documented in this paper. From the results of the visual inspection a certain section of each screen was cut for further detailed microscopic study to better understand the scaling and plugging mechanism, as well as microscopic geometry of the plugged and corroded zone.
The results highlighted the importance of the corrosion in the base pipe on the observed performances. All the studies pointed toward the flow dependence corrosion behavior, and the role of the water cut on the corrosion rate. The wire wrap screens have been in service for less than a year, yet the extensive corrosion led to creation of several holes in the pipe. The study showed the corrosion initiated from inside the pipe. Similarly, the corrosion of the slotted liner samples showed a strong flow dependent corrosion rate, where the corrosion rate on the slot/formation interface was slightly higher. The mesh screen showed very high plugging percentage by formation fines, where a thick film of clay and fine sand covered the space between the mesh and the base pipe. The results indicated that an inappropriate design of the mesh and pore could cause significant plugging.
This paper provides several field examples of the corrosion and plugging of the standalone screens. The results could help engineer to better understand the risk of corrosion and plugging on the standalone screen design. This paper provides some general guidelines for assessing the scaling and corrosion potential at field condition based on the results of the screens studied in the paper.
Rigless Pre-Workover Diagnostic of a Dual String Completion
Authors: Safar Emad , Al-Khatrash Mouzah , Al-Hazeem Fatema , Prosvirkin Sergey , Karantharath Radhakrishnan , Najdi Ahmad , Al-Shatti Mohammad 
Published: October 2018

Abstract
One of the advantages of having a dual string completion is the option to develop and produce more than one reservoir simultaneously, whereas there are considerable disadvantages too and one of such is managing the integrity of the two strings intact throughout the life time of the well. In this paper, a case study from Ahmadi Field is presented highlighting the need for effective surveillance methods to identify issues with dual string completion and successful implementation of workover.
Spectral Leak Detection (SPEC-LD) along with High Precision Temperature (HPT) tool was used to pin point the exact leak locations in the tubing strings prior to attempting the workover. Spectral Noise Tool is a passive tool with a high sensitivity hydrophone designed to record sound in the frequency range of 8 HZ to 60 KHZ. Analysis of noises recorded in various frequency ranges allows the location of flow-related features, such as wellbore flows, casing and tubing leaks, perforations, cement channelling and flows through the rock matrix and fractures. The SPEC-LD combined with a high-precision temperature (HPT) tool was found highly effective in pinpointing leak sources and quantifying it.
Ahmadi Field is one of the prolific oil fields in South Kuwait and has many dual string completions. In this paper, a case study is presented where the SPEC-LD tool was effectively deployed to identify leaks in a dual string completion. The leak and communication between the strings resulted in higher water cut from the short string which was producing at zero water cut. Based on the logging results, the well was successfully worked over in a cost-effective manner to improve the production. The workover also resulted in reducing the water production from the well, thus saving water treatment cost prior to disposal. Knowledge of the tubing condition prior to deploying the workover rig was found useful and effective in selecting the proper workover procedure, tools and techniques.
Blindly doing workover without knowing the tubing condition and well integrity generally results in the application of wrong workover processes and techniques causing overspending and safety concerns. Evaluating the condition of the tubing string and pinpointing the leaks was found useful in planning proper workover and thus minimizing the cost as well as bringing the wells back on line on minimum time. The main message from this paper is the benefit of using appropriate evaluation techniques prior to attempting any workover to save both time and money.