bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Real Case Study: "Well Monitoring System and Integration Data for Loss Production Management" Consorcio Shushufindi
Authors: Goyes J.. , Biedman D.. , Suter A.. , Navarre P.. , Tortolero M.. , Ostos M.. , Vargas J.. , Vivas P.. , Sena J.. , Escalona C.. 
Published: June 2014

Abstract
The Ecuadorian State opened the industry to "Service Contracts" during 2012 with the main objective to increase production of its mayor fields through the implementation of new technologies. Consorcio Shushufindi (CSSFD), a consortium formed by Schlumberger, Tecpetrol and KKR, was awarded such a contract. Between the commitments done by the CSSFD is the implementation of the Asset Integrated Management Center (MIA) for Shushufindi Field as a means to improve collaboration between the different stake holders to increase production and make the operation more efficient.
The CSSFD contract is based on incremental production and therefore it is of the highest importance to produce its target reservoirs. In order to achieve this target is necessary monitoring continuously some operational parameters, with different frequencies, in the field. To obtain that scenario is necessary to create an integrated system that combines both frequencies to detect loss production in wells operated with ESP system.
In order to support the daily operation and the cumulative loss production calculation, it has created an integrated monitoring system called "Well Status". This system was designed to automatically update the resume for the current situation of the field, based on the well status. Beginning with the downtime, the production loss is calculated using the last well test. As is known, the well test supplies the potential production per day. This calculation is performed for wells with high and low frequency data, allowing prioritizing intervention to those wells which report unplanned shutdown and have higher potential.
This workflow allows the engineers in the field and Office to identify the loss production caused by some issues the ESP system, and this analysis is based on ESP status tag. This analysis is continuous using real-time data that is transferred from the field.
Intelligent Energy - Changing How Work Gets Done.
Authors: Quaadgras A.. , Edwards A. R. 
Published: June 2014

AbstractThere is more to Intelligent Energy than information and communications technology. Getting full value from digitization in oil production requires rethinking how groups get work done, and providing the organizational capabilities to support that change.A study of six major oil and gas companies that have all been implementing Intelligent Energy for more than five years was carried out. In this study we find that in order to implement changes at the asset level, we need to focus not just on providing an information and communications technology backbone, but more importantly, on documenting and clarifying business and group interaction rules, roles & accountabilities, and on providing ongoing coaching and feedback to all participants.We also find that implementing effective group operational decision making across a global firm requires active involvement of local groups as well as global support, in the form of specific global organizational units that sustain and scale new ways of working. These global units are not implementing change top-down; rather they are working center-out. They coordinate efforts around continuous improvement and integration of effective practices, adoption through business pull, global governance by top operational leaders, and multiple forms of ongoing coaching. This paper will summarize the results from the study and make recommendations for the effective implementation of Intelligent Energy.
Distributed Acoustic Sensing for ESP Understanding and Surveillance
Authors: Allanic C.. , Frangeul J.. , Liebeck M.. , Carbonnier B.. , Naldrett G. J. , Farhadiroushan M.. , Clarke A.. 
Published: June 2014

Abstract
Distributed Acoustic Sensing (DAS) technology from optical fibers is already identified as very promising for reservoir monitoring1 and especially for seismic applications2 with many stakes today in all Oil&Gas companies. DAS surveys can also have more "production" oriented applications for in-well surveillance and more specifically in complex well configurations and completions. This paper relates an in-well trial from permanent optical fibers installed in a horizontal, multi-lateral and ESP (Electrical Submersible Pump) activated well.
Two types of fibers had been installed permanently in this well: a multi mode fiber and two single mode fibers linking FBG’s (Fiber Bragg Gratings) optical gauges. These fibers were used to simultaneously acquire distributed temperature from DTS and distributed acoustic data from DAS.
The first objective of this in-well trial was to use the DAS data to improve or better constraint the temperature interpretation to get more reliable flow profiles. The acquisition sequence was designed to generate several temperature disturbances using different ESP frequencies leading to different production rates.
DTS interpretation has been performed and results are now more in accordance with previous interpretations. However, the ESP location introduced noise which made difficult to interpret the DAS signal from the close producing zones. For that reason, the first objective was not fully reached. It should be noticed that this was the first DAS acquisition in a well equipped with an ESP. The paper describes also how DAS data were investigated to open a new application on the understanding of pump behavior and possible optimization of pumps.
Direct Measurement of Gas Content Without Coring
Authors: Gray Ian , Singh Harjeet , O'Brien Andrew 
Published: June 2014

Abstract
This new process enables the quantitative determination of the gas content of coals and other strata, such as shales or conventional reservoir rocks during overbalanced open hole drilling. This paper presents the results of a field trial through coal seams in Central Queensland where the system was tested and showed favourably comparable results to those obtained from gas content measurement by conventional core desorption in coals.
The system involves drilling in overbalanced mode through so that no reservoir fluids enter the well bore. Under these conditions the only material produced is that cut from the hole. This comprises cuttings and may also include gas and liquids contained therein. This material rises up the annulus and is diverted by a rotary seal to a cyclonic separator. This separates the free gas while the mud and cuttings overflow from the base of the separator and over a shale shaker. The free gas volume is measured directly while the cuttings are separated from the mud on the shaker and are sampled into canisters so as to permit measurement of any gas that may desorb from them freely or further after crushing.
The system thus enables the capture and measurement of all gas contained in the drilled strata with the exception of that desorbed during the brief period that the cuttings are on the shaker. This lost gas is small and may be readily estimated. The system is direct and simple and has the potential to replace core sampling and other more indirect and complex geophysical techniques to measure the gas contained in strata.
Research on Fractured Horizontal Wells Productivity and Productivity Influence in Shale Gas Reservoir
Authors: Xie Weiyang , Li Xiaoping 
Published: June 2014

Abstract
Based on large number of shale gas exploration and development literature research, this paper describe the characteristics, accumulation regularity, adsorption and desorption properties of shale gas which are different from conventional gas reservoir. Langmuir isotherm law and Fick diffusion law are used to established the desorption gas steady diffusion rate expression. Three research works have been done, first, established the production formula of fractured horizontal well based on the model of Genliang Guo rectangle fractured horizontal flow, fracture angle and desorption gas steady diffusion rate are employed to improve the production formula. Second, interact of fractures and desorption are considered, equivalent filtrational resistance is used to establish a capsule model of shale gas steady flow, a new production formula of fractured horizontal well in shale gas reservoir has been derived by the new flow model. At last, rationality of the two formulas has been proved by the calculation of programing based on the field data. Analysised the production influence of formation parameter, horizontal well drilling factors, fracturing effect and desorption gas steady diffusion rate. The production formula of fractured horizontal well in shale gas reservoir and the research of production influence can be used in productivity prediction of later period shale gas reservoir fractured horizontal development. It can also interpret the parameters selection of drilling and hydrofracture more accurately for shale gas reservoir. Optimization design of shale gas reservoir development mode can be improved by the production formula and effect factors research. Desorption gas steady diffusion rate computational method provided us with deeper research about years of stable production, proration, reasonable production system in shale gas reservoir development and how desorption affect production of fractured horizontal shale gas wells.
A New Geomechanical Model Explaining Source Mechanisms of Events Induced by Hydraulic Fracturing in Shale
Authors: Eisner Leo , Stanek Frantisek 
Published: June 2014

Abstract
Optimization of stimulation is key to successful development of unconventional reservoirs. Microseismic monitoring is the most powerful tool to help us understand where and what is happening during and after the stimulation. Yet very little is understood about the relationship between microseismicity and hydraulic fractures: some believe microseismic events are part of the hydraulic fractures, some believe they are resulting from stress changes and fluid leak-off. Microseismic datasets with accurate event locations complemented with source mechanisms lead us to a new level of understanding of the interaction between hydraulic fracturing and seismic response. There are at least four geomechanical models to explain observed failure mechanisms and the opening (or closing) of hydraulic fractures (seismic tensile opening, leak-off cloud of seismicity around the hydraulic fracture, shearing between aseismic tensile opening and horizontal fractures shearing on vertical planes). Unfortunately none of these models is consistent with observations presented in this study. Hence we developed a new geomechanical model of bedding plane slippage and vertical shearing induced by hydraulic fractures in shale reservoirs.
We present a case study including detailed source mechanism inversion for a microseismic dataset from hydraulic fracturing of a shale gas play in the North America. We observe source mechanisms dominated by shear failure with dip-slip and strike-slip sense of motion. The dip-slip mechanisms are prevailingly oriented with shear planes along the maximum horizontal stress. This can be explained as slippage on beddings planes caused by aseismic opening of hydraulic fractures. The strike-slip mechanism show small but real components of non-shear deformation. This can be also explained as slippage on vertical plane perpendicular to maximum horizontal stress with slight opening as these events are direct part of the hydraulic fracture. This model explains large energy difference between seismic and hydraulic energy, and prevailing orientation of the shear planes of the induced microseismic events. In addition, the bedding planes are weak planes in the shale formation likely to fail. The model can better constrain fundamental parameters of induced hydraulic fractures and describe hydraulic fractures and their interaction with the shale plays.
Stakeholder Concerns Against Shale Gas Developments in Europe - The Relevance of Water Management
Authors: Heinz Walter , Hiller Dieter 
Published: June 2014

Abstract
The exploration of shale gas resources in Europe is moving at a slow pace, despite the fact that drilling for reservoir characterization is essential for any further planning. Whether shale gas development in certain regions is economically feasible at all and what such development activities might entail can’t be determined in the absence of critical data. Yet, there is widespread public resistance that influences political decision making and permitting, and that sometimes doesn’t even allow for exploration. Most of the stakeholders concerns are related to perceived environmental risks for water resources as a result of hydraulic fracturing. The main themes are concerns about the contamination of water bodies by fracturing chemicals, methane or flowback water, or concerns about the depletion of groundwater and surface water.
While some of those perceived risks may be overestimated or unsubstantiated, there are real risks that have to be addressed by thorough assessments of the environmental, health and social impacts, and by an integrated approach to water management from sourcing to final disposal. This includes the transportation and distribution logistics for water and wastewater movements. It is essential to establish relevant reference and baseline data on groundwater and surface water systems well ahead of project implementation, to assess risks in a fashion that is understood by interested stakeholders, to define proactive and reactive resource protection measures, and to monitor performance.
This paper suggests an integrated approach to water management that combines the elements of impact assessments, scientific and technical data gathering, and the monitoring of potential impacts across the life cycle of a shale gas project, as well as sourcing, transportation and disposal strategies. All results and measures taken need to be communicated and documented in a clear and transparent manner.
CBM Development Scenario Optimization for Production Sharing Contract, Case Study: Sumbagsel Field, Indonesia
Authors: Ferdian Felik , Ilyas Adrinal , Mediyanti Vina 
Published: June 2014

Abstract
Indonesia according to research by Resource International Inc. Advance. (ARII) along with the Directorate General of Oil and Gas – Ministry of Energy and Mineral Resources has potential resource 453 TCF of CBM which is divided into 11 (eleven) basin on the island of Sumatra, Borneo, Java and Sulawesi. The results of CBM product is expected to be a solution to Indonesia's potential energy shortages in the future relying on energy sources from oil and natural gas.
The utilization of CBM in Indonesia following the fiscal term of Production Sharing Contract (PSC) with a validity period of 30 years. CBM reservoir characteristics are different from conventional gas with smaller permeability, predominantly adsorbed gas and under-saturated conditions require draining the water content (dewatering) before the production period that requires careful planning to produce a viable project either in terms of technical, economic and commercial.
Simulations conducted in Sumbagsel Field in Southern Sumatra, Indonesia, seeking development planning optimization by creating drilling scenarios of CBM wells with a certain amount of accumulation to get a good view of the economic indicators of Net Present Value (NPV), Internal Rate of Return (IRR), Profitability Index (PI) and Payback of Time (POT). The results showed that CBM development can not be done with conventional gas development model approach which uses ‘chuck management system’ to control the production, while the properly management is required in the development of CBM drilling where the number of production wells will be proportional to the increase of production. Knowledge of reservoir characteristics and production optimization management of the number of drilling development wells during fiscal term contract with the production sharing contract will result in the economic development of CBM.
A Physics-Based Method for Production Data Analysis of Tight and Shale Petroleum Reservoirs Using Succession of Pseudo-Steady States
Authors: Shahamat M. S. , Mattar L.. , Aguilera R.. 
Published: June 2014

Abstract
Analysis of production data from tight and shale reservoirs requires the use of complex models for which the inputs are rarely known. The same objectives can also be achieved by knowing only the overall (bulk) characteristics of the reservoir, with no need for all the detailed rarely known inputs. In this work, we introduce the concept of continuous succession of pseudo-steady states (SPSS) as a method to perform the analysis of production data. It requires very little input data yet is based on rigorous engineering concepts which works during the transient as well as the boundary dominated flow periods.
This method consists of a combination of three simple and well-known equations: material balance, distance of investigation and boundary dominated flow. It is a form of a capacitance-resistance methodology (CRM) in which the material balance equation over the investigated region represents the capacitance, and the boundary dominated flow equation represents the resistance. The flow regime in the region of investigation (whose areal extent varies with time during transient flow) is assumed to be pseudo-steady state. This region is depleted at a rate controlled by the material balance equation.
The initial flow rate and flowing pressure are used to define the resistance, and the distance of investigation defines the capacitance. The capacitance and resistance are then used in a stepwise procedure to calculate the depletion and the new rates or flowing pressures. The method was tested, for linear flow geometry, against analytical solutions for liquids and numerical simulations for gas reservoirs, exhibiting both transient and boundary dominated flow. Excellent agreement was obtained, thus corroborating the validity of the method developed in this paper.
The proposed method is easy to implement in a spreadsheet application. It indicates that complex systems with complicated mathematical (e.g. Laplace space) solutions can be represented adequately using simple concepts. The approach offers a new insight into production analysis of tight and shale reservoirs, using familiar and easy-to-understand reservoir engineering principles.
An Integrated Approach Towards a Holistic Sedimentological and Pore-Scale Characterisation of Fine-Grained (Shale) Unconventional Reservoirs
Authors: Dasgupta K.. , Kostic B.. 
Published: June 2014

Abstract
For a holistic characterisation of fine-grained unconventional reservoirs, our integrated approach utilises coherent, reproducible datasets and refined work practices carried out within a comprehensive quality management system. A typical reservoir characterisation includes integration of sedimentological, structural and pore-scale datasets, however, the specific work flow design depends entirely on the nature of the problem and the availability of appropriate data.
This paper illustrates an example of unconventional reservoir characterisation of a fine-grained formation from the North Sea where the specific aims were to establish the depositional framework for recognising sedimentary environments, recommend sample locations to target specific queries within the sedimentological context for petrographical and geochemical analyses, to investigate what porosity types are present and to assess ‘brittleness’ of the rocks.
First and foremost, high-resolution interpretative graphic core descriptions were carried out at 1:24 scale, utilising Badley Ashton's mudrock-specific lithotypes and depositional packages schemes. Lithotype characterisation uniquely captures very fine-scale attributes (bed to subbed scale), whilst upscaled depositional packages (bed-stack scale) provide a more holistic characterisation from core, as well as from wireline and image logs, where available. Plugs coded by the above descriptors were selected post-logging, for detailed petrographical and geochemical analysis including Rock-Eval pyrolysis within the sedimentological/structural context. Mineralogical data was acquired by whole-rock and clay-fraction XRD analysis, whilst pore-scale fabric/textural investigation were undertaken by conventional light microscopy and BS-SEM. A subset of the plugs was subjected to FIB SEM analysis to characterise any potentially organic matter associated pore system. All these different strands of data were then integrated to evaluate and link the depositional system/sedimentary environment, storage capacity and brittleness of the reservoir in order to assess the overall reservoir potential of the fine-grained formation.
Water Loss versus Soaking Time: Spontaneous Imbibition in Tight Rocks
Authors: Lan Q.. , Ghanbari E.. , Dehghanpour H.. , Hawkes R.. 
Published: June 2014

AbstractThe combined application of multi-lateral horizontal drilling and multi-stage hydraulic fracturing has successfully unlocked unconventional tight hydrocarbon reservoirs. However, the field data show that only a fraction of the large water volume used in hydraulic fracturing treatments is recovered during flowback operations. The fate of non-recovered water and its impact on hydrocarbon production are poorly understood.This paper aims at understanding the relationship between water loss and rock petrophysical properties. It also investigates the correlation between water loss and soaking time (well shut-in time). Extensive spontaneous imbibition experiments are conducted on downhole samples from the shale members of the Horn River basin and from the Montney tight gas formation. These samples are characterized by measuring porosity, mineralogy and TOC. Further, a simple methodology is used to scale up the lab data for predicting water imbibition volume during the shut-in period after hydraulic fracturing operations.
Environmental Stewardship: Lessons for European Unconventional Gas From the United States and Australia
Authors: Wilkinson Paul , von Lany Peter , Lane Alexander 
Published: June 2014

Summary
Europe is on the cusp of an expansion in the development of unconventional gas resources, and many analysts are turning to the United States (US) and Australia to learn lessons from markets at different stages of the development curve. To date, most attention has been focused on similarities and differences in geology, service industry, and gas price while consideration of environmental stewardship has been dominated by concerns over the potential environmental and health impacts of hydraulic fracturing. Broader issues of local water security, wastewater management, and landscape impact have, in contrast, received less attention.
To address these issues, the authors take an alternative look at the European market by using experiences in the US and Australia to consider the risk-management practices, regulatory measures, and stakeholder-engagement techniques that have achieved greatest success in stimulating the industry while, at the same time, protecting environmental assets. Although the industries in the US and Australia exhibit notable differences to those that may develop in Europe, several overarching observations can be made. The importance of stakeholder collaboration, transparency, and carefully defined boundaries of jurisdiction are some of the key factors identified.
Drawing lessons from these examples and others, the authors conclude by identifying three initiatives essential to the emergence of a viable, publicly acceptable, and sustainable unconventional gas industry in Europe:
Collecting robust and reliable environmental baseline data Using and communicating sound science Implementing collaborative governance
Failure to implement these initiatives could stifle projects, breed uncertainty, promote conflict with existing industries and the public, and potentially discourage investment. Conversely, by implementing the three recommendations, Europe would be in a better position to encourage unconventional gas development in a manner that secures social and economic benefits while maintaining high levels of environmental stewardship.