bluuebunny/crossref_metadata_2025_split huggingface dataset:
Artificial Neural Networks in Drilling Troubles Prediction
Authors: Lind Yuliya B. , Kabirova Aigul R. 
Published: September 2014

Abstract
Drilling of oil and gas wells is a basic process in production of hydrocarbons. Up to now drilling projects are often being designed on the base of segmental data and primary analysis of drilling experience, which is ineffective under modern drilling conditions. A possible solution of this problem consists in computer analysis of data on earlier drilled wells with the use of modern information technologies. Authors propose methods for prediction of probable troubles occurring while drilling new wells on the base of information on well stock of the oilfield using efficient data mining tools – artificial neural networks. Structural and parametric identification of a neural network solving the formalized problem of functions approximation has been conducted. Results of computational experiments on real data show effectiveness of software developed.
Overview of Solids Transport Studies and Applications in Oil and Gas Industry – Experimental Work
Authors: Li J. , Luft B. 
Published: September 2014

Abstract
The transport of solids is encountered in well bore drilling, completion, intervention and production operations. It is affected by many variables and the complexity of the process presents challenges to the field engineer who is trying to determine how these parameters affect solids-transport even if only one of these variables is changed. Historically, solids-transport studies focused mainly on determining the minimum critical velocity to prevent the formation of a stationary debris bed in the wellbore annulus for conventional rotary drilling with mud fluids. Over the past 10 years, the research and development focus has been on obtaining information related to the prediction of the equilibrium solids concentration profile along the whole well path during tripping in, the wiper trip speed during tripping out, and the prediction of the hole-cleaning time. Various computer models have been developed that, to some extent, guide the field engineer in the design and optimization of the solids transport process. However, due to its complexity and incomplete experimental data, a comprehensive, proven and reliable model still does not exist at present.
In this paper, based on 20 years of research experience, the authors present a review of previous approaches to the study of solids transport in both drilling and well interventions with emphasis on experimental studies. An overview of the theoretical study of solids transport is presented in a companion paper (Li and Luft, 2014). The basic tests required to collect comprehensive laboratory data in support of the development of a semi-empirical theoretical model to simulate the hole cleaning process, are also discussed. To date there is still no satisfactory solids transport software model commercially available for the oil industry. This paper provides some insight into and understanding of the complexity of the solids transport process, a general guide for necessary laboratory testing and some recommendations for future research related to this subject.
Bulk Transfer on Oil Rigs: System Optimised through Pilot Testing
Authors: Ratnayake Chandana , Saasen Arild 
Published: September 2014

Abstract
Pneumatic conveying is a material transportation process used on nearly every offshore rig, in which bulk particulate materials are moved over horizontal and vertical distances within a piping system with the help of an air stream. Using either positive or negative pressure of air or other gases, the material to be transported is forced through pipes and finally separated from the carrier gas and deposited at the desired destination. This mode of bulk solid transportation is efficient compared to other modes of transportation because of the flexibility of installation and application on the rigs. Although pneumatic conveying has seen increased use on drilling rigs, there are still many major problems hampering its employment in a wider range of conveying applications like high energy consumption, excessive product degradation and system erosion, unstable plugging phenomena, severe pipe vibration and repeated blockages. Further, the lack of simple procedures for the selection of an optimal system, thus use of sub-optimal system are major problems in pneumatic transport system design and rig applications.
This paper presents a scientific investigation aiming to design and optimise offshore bulk transfer systems for handling of weighting materials like barite, clay type materials like bentonite and oil well cements. The approach is based on a scaling-up technique involved with pilot scale testing. Test procedures, relevant theories on gas-solid two phase flow in pneumatic transfer and results are presented in the paper. Finally, a detailed procedure on how to optimise bulk transfer on drilling rigs is presented.
The High-Temperature Electrical Submersible Pump for Production of High-Viscosity Oil Using SAGD Technology
Authors: Poshvin E. V. , Sergienko A. V. , Komarov O. V. , Tolstoguzov O. A. , Malyavko E. A. 
Published: September 2014

Abstract
There is a growth trend of hard-to-recover oil reserves around the world, due to the development of heavy and viscous oil. Heavy oil is becoming an essential part of the raw material base now. One of the technologies of extra-viscous oil production is steam assisted gravity drainage (SAGD) which imposes significant operating restrictions on used equipment. First of all, it is the ability of the submersible unit to work at high temperatures of the pumped liquid. Equipment testing with the establishment of its efficiency and reliability in conditions close to the real operation is a very important issue.
To solve this problem stand testing was conducted to identify the most temperature-loaded elements of serial electrical submersible pump (ESP), and the complete high-temperature ESP was designed and manufactured. The high-temperature ESP incorporates new design solutions and new materials.
To confirm technical characteristics of new ESP, tests were carried out on the stand-well for research of submersible equipment at temperatures up to 250 °C. The unit was tested in periodic mode with a total time of work 80 hours. Fluid temperature is maintained during stops not less than 160 °C and during testing - not less than 180 °C. In the course of work head-energy parameters of unit were measured, as well as the temperature on the housing of protector and motor.
Testing of the complete high-temperature ESP was successful. It allowed avoiding costly and time-consuming stage of debugging in the field conditions. The conducted work confirmed the possibility of the effective ESP utilizing for SAGD technology.
Mature Field Gas Lift Optimisation: Challenges and Strategy, Case Study of D-Field, Malaysia
Authors: Ismail W. Rokiah , Trjangganung Kukuh 
Published: September 2014

Abstract
As the world's population continues to grow, the energy demand is forecasted to increase directly proportional by 52% in between 2010 to 2035 (OPEC, 2013). With the oil prices predicted to be stable in the long run and expected to be as high as $165 per barrel by 2035, the search for more oil continues (OPEC, 2013). An estimation of 70% world's oil and gas production originates from mature fields with recovery at an average of 35% worldwide (Hull, 2012). This proves that there are still opportunities to recover more through enhanced primary, secondary or tertiary recovery in creating further hydrocarbon flow of a mature field.
Lower reserve with high operating and field redevelopment cost for a tertiary recovery program has deteriorate the economics for a mature field. Developing tertiary recovery for a mature field requires major modification at surface and sub-surface. Leaving the operators with the challenge to maximize recovery under current operating conditions and limited work scope of a primary recovery mainly through artificial lift method such as gas lift in oil wells.
Gas lift has been part of the primary oil recovery ever since the 1800s and the effectiveness has proven to aid the acceleration of oil recovery in a well for centuries (Gas Lift: Wikipedia, 2014). Deterioration in surface equipment and sub-surface well completion condition in a mature field, such as worsening well integrity with leaks and holes, inaccurate production metering, instability of gas compressor availability and efficiency, has resultant in the ineffective of gas lift distribution and injection downhole.
Despite the challenges faced, through prudent technical analysis and effective execution at site, the production of D-field in Malaysia has managed to increase up to 8,000 bbl/d (barrel of oil per day) instantaneously merely through production and gas lift optimization exercise.
This paper will run through the challenges faced and the technical analysis conducted in overcoming the handicap at site. This has led to the successful implementation/formulation of production philosophy and strategy to overcome challenges under different production scenarios, resulting an instantaneous production gain of some 30%. To some extent the production has been sustained and the decline arrested.
Up-to-Date and Effective Solutions for Liquidation of Accidental Oil Spills in Oil Production
Authors: Golivkin R. G. , Kuznetsov I. V. , Kornilina N. R. , Dymov I. S. , Nemov D. A. 
Published: September 2014

Abstract
Strict requirements to environmental safety in oil production today determinate special attention to the measures of minimization of ecological damage from emergency situations, as the consequences of several methods of accidental oil spills liquidation do not meet high demands or are not studies well.
Most of common technologies of accidental oil spills liquidation have several disadvantages. For instance, mechanical methods have low speed of response, do not manage operations with oil sludge with high viscosity level and have low portability of the equipment. They can be hardly applied in case of rugged reliefs and in different climatic conditions.
Common physico-chemical methods (appliance of sorbents) are not efficient enough as well, because they lead to accumulation of waste, require fining and waste utilization.
This article is devoted to innovative developments in the sphere of accidental oil spills liquidation and recultivation of soils and waters, which meet modern requirements.
Power Distribution in Subsea Developments: A System Engineering Perspective
Authors: Moreno-Trejo J. , Markeset T. 
Published: September 2014

Abstract
Subsea developments represent several technical challenges for O&G companies. The tie-back solution has been used in the industry to exploit remote fields or connect systems directly to onshore facilities or nearby existing production facilities. As it can use existing resources/facilities, this solution may save capital and operational expenses (CAPEX and OPEX). Moreover, marginal fields may become commercially viable if they are connected to an existent platform.
However, as fields are located farther away, limitations related to flow assurance, power and system distribution make it more difficult to assign resources to these projects. Systems such as power and control equipment may be located on platforms or subsea, and the choice of solutions is based on cost-saving potential, reliability and environmental care considerations. Power and control systems also have to be capable of working for long periods and functioning without interruptions. Distribution systems’ study factors also concern distance from the power source to the seabed. For longer distances, the system should be designed to repeat signals from one subsea station to another.
To explain some of the challenges and limitations for working subsea, a general description of power systems is provided. The study also discusses the role of system engineering in subsea projects and how it contributes to overcoming technical limitations and improving system performance. Good communication between all the groups is important and may reduce project errors and the need for rework.
The study discusses some considerations that should be taken into account during the concept selection to prepare the system for current and future requirements. The type of umbilical for the power and control groups is also discussed. These are used to transmit communication and power to the system.
Applications: The paper presents the role of system engineering in subsea projects. It identifies some parameters in the system and explains the technical limitations caused by loads and power requirements in subsea projects.
Results, Observations, and Conclusions: System engineering should establish strong communication between the groups working internally in the project. They provide an overall view of the system that is critical to the optimization of resources. Decisions on where to place distribution systems depend on the location of the subsea installation as the voltage drop and power loss is proportional to the distance at which the power source is located.
Development of Heavy Oil Deposits and Natural Bitumen With Small and Variable Thickness of the Formation the System of Horizontal Wells
Authors: Korepanova V. 
Published: September 2014

Abstract
This work is devoted to actual topic «Development of heavy oil deposits and natural bitumen with small and variable thickness of the formation in the system of horizontal wells».
This method presupposes drilling of pair of injection well and producing well over the thickness of the oil formation. Here with, producing well places under level of injection well, steam injection performs in injection well and extraction of oil performs from producing well. Changes in drilling trajectory of injection well are calculated in accordance with the mathematical model takes into account the anisotropy of oil formation. Offered method of exploitation provides creation of favorable conditions for effective exploitation of all parts of oil pool for completely deplete of it.
Heavy oils and natural bitumens classified as hard extraction of hydrocarbon feed. It has a high viscosity in natural conditions unlike light oils. That's why traditional methods of oil production is insufficiently effective in the case of heavy oils and natural bitumens. World's experience of heavy oils and natural bitumen production shows that there are wide range of methods:
The Effect of Field-Geological Characteristics Terrigenous Reservoirs on the Decrease Injectability after Well-Workover Operation
Authors: Elizaveta Soboleva 
Published: September 2014

Abstract
Reservoir pressure is reduced because the intensification of the selections and low compensation fluid withdrawal injection.
Engineers have made a program to increase injectability, but there is a problem. This problem is a short duration of effect it after well-workover operation (acid treatment, hydraulic fracturing).
Technological mode of injection wells and planned task is not meting.
Landing String Slip System: State-of-the-Art Design to Minimise Pipe Crushing Problems
Authors: Amezaga Federico , Rials Joseph Ross , Heidecke Karsten 
Published: September 2014

Abstract
New oil and gas reservoir discoveries in extreme deepwater conditions have become common. Constructing wells in these deepwater environments has challenged the industry to develop new technologies for reaching extended depths while focusing on limitations of the tubular goods due to excessive crushing loads from handling tools. To address this situation, a new landing string slip system with improved slip crushing capabilities has been designed and tested in the GOM. This hydraulically operated slip system was designed for 37 1/2-in. rotary profiles. It has a 1250-ton capacity and a pipe range of 5 1/2- to 7 5/8-in. Design considerations focused on limited maintenance, tubular guiding, and pipe centering capabilities. The main focus, however, was on reduced slip crushing forces to lessen the need of slip-proof pipe and to bring string capacities closer to tensile limitations.
To evaluate slip crushing capabilities, laboratory tests were performed on landing strings with varying wall thicknesses and yield strengths. Both strain gages and ID measurement tools were used to evaluate the slip crushing performance of this tool. The testing and results are detailed within this paper.
Applying results to field applications was the next challenge. The accepted application method is the Spiri-Reinhold equation; however, it is limited because it requires gross assumptions that do not accurately predict behaviors of critical load systems. The test data was used with the Spiri-Reinhold equation to produce a method of practical yet accurate evaluations of critical strings while highlighting important considerations for comparisons of results.
In this paper, the authors detail the operational advantages provided by this slip system, provide a comparison between the two testing methods, discuss the results obtained and their application to the Spiri-Reinhold equation, and highlight factors that must be considered when evaluating critical strings for which slip crushing forces are nearing pipe yield points.
Evaluating Gas Reserve and Project Cost Using Multistage Scenario Process on Gas Development Project
Authors: Asmoro Trian Hendro 
Published: September 2014

Abstract
The development phase of oil and gas fields is challenging, since wells need to be drilled and assessed for oil and gas reserves, and production facilities need to be built. It will only be executed after the exploration phase shows attractive economic indicators (IRR, NPV and payout time). Marginal gas reserves and high development costs will result in marginal economic indicators of the project compared to the company expectation.
The marginal economic indicators have created the mechanism for tight project control during project execution, in order to maintain acceptable NPV. The objective is that the thresholds of model parameters need to be defined on a staging basis to guide the project on an economical track. The thresholds will confine the limit of drilling and facilities cost which can be spent according to reserve scenarios.
The monitoring model is then built by combining the development project economics using multistage scenario tree. A solid model needs to be built and tested using Monte Carlo simulation to generate the drilling and facilities costs. Thus, the model will result simulated economic indicators which will limit of maximum allowable project cost for each reserve scenario.
This paper shows that the economic feasibility of a gas field project at the development phase can be analyzed using the multistage scenario process. Therefore, the key activity is to monitor the performance of the project, i.e. reserve verification, drilling and facilities costs, in addition to the project schedule. Finally, decisions about the project may be made at each stage according to the portfolio profile of the company.
Ichthys Field Development - Implementation of a Multi-Disciplinary Well Optimisation Workflow for a Large Gas-Condensate Reservoir
Authors: Kawasaki A. , Batiot S. , Ion A. 
Published: September 2014

Abstract
Optimisation of development well locations is a critical field development objective to ensure maximisation of hydrocarbon production and gas plateau duration. In a large reservoir with relatively sparse well control, significant inter-well uncertainty can exist, resulting in a high degree of subjectivity in the selection of production well locations. Following the implementation of a comprehensive workflow to construct multiple geologic realisations of the Brewster reservoir, a two-step process was developed to: 1) objectively identify optimum production well locations that suited a selected range of geologic models, and 2) subjectively refine these locations to satisfy practical requirements.
Optimum well locations were initially identified using a systematic approach covering a wide range of geologic scenarios based on an objective to maximise gas plateau duration. Resulting well locations for each realisation were then consolidated into a single well pattern using a frequency mapping technique. Subsequently, a subjective approach was adopted to refine these well locations based on considerations, including targeting of structurally high points, minimum inter-well spacing, step-out from subsea drill-centre locations, maximising the value of data acquisition (distance from existing well control) and reducing well construction complexity (minimising lateral step-out and drilling in non-preferred azimuth). Concurrently, optimisation of well geometry and total depth was investigated which indicated the potential for drilling/completion cost savings with negligible impact on predicted production performance.
The integrated, multi-disciplinary nature of this methodology was paramount in effectively communicating and satisfying well planning/execution objectives between key project disciplines.
The Coniston and Novara Development in Western Australia - Offshore Challenges met with Solutions
Authors: Sankoff Roumen D. , Di Martino Gianluca , MacDonald Shona , Marshall Craig S. , Smith Anthony 
Published: September 2014

Abstract
The development of heavy oil accumulations presents difficult engineering, technological and geological challenges that need to be overcome to produce economically viable projects. Even a large oil accumulation can be deemed unattractive for development in cases that combine a high cost environment with complex geological setting and unfavorable fluid dynamics. This paper highlights the challenges and presents the subsurface solutions that unlocked the value of an offshore heavy oil accumulation, 32 years after it was first discovered. Within the context of the overall development plan, the paper describes:
The design of the offshore well test that delivered 11,244 bbl/d 15.7°API oil and proved the production capacity of the reservoir and the conceptual well design. Workflow for confirming the existence of a compositional gradient and characterization of a biodegraded oil column. A novel approach to evaluation of inflow control devices (ICD) and its implementation in the well design. An ICD modelling tool developed specifically for direct comparison of different ICD geometries.
The paper also presents the field history to date – from the early failures in recovering hydrocarbons using conventional methods, through to the enabling technologies that made Coniston and Novara a viable project.