bluuebunny/crossref_metadata_2025_split huggingface dataset:
Developing Project Management Professionals in QATAR
Authors: Jaidah Bader AL 
Published: December 2015

Abstract
TAFAWOQ, which means "excellence" in Arabic, was established in 2011 as a regional non-profit Project Management Centre of Excellence, to deliver a world-class course program which aims to develop the competencies of project managers for capital projects in the State of Qatar and the GCC.
The Hamad Bin Khalifa University (HBKU), Qatar Petroleum (QP) and Qatar Shell developed the TAFAWOQ initiative in supporting Qatar National Vision 2030 (QNV 2030), one of the most ambitious development programs in the world. This program is accompanied by investment projects valued at more than US$ 230 billion.
A Memorandum of Understanding between the three partners was signed in October 2012.
This paper illustrates how TAFAWOQ contributes to the development of the competencies of project managers and other participants in project teams in Qatar and the region. In summary, this is through:
The delivery of a world-class course program for project managers and those participating in projects in the State of Qatar and in the GCC region. This program is developed in conjunction with the Shell Project Academy, Cranfield University in the UK, Technical University Delft in The Netherlands, Queensland University of Technology in Australia, and the University of Texas in Austin.
Community Events to promote networking and provide the project management community with a forum to discuss major subjects regarding project management in the GCC region.
Tailored courses to address specific requirements of regional companies and delivery of courses at their premises.
Toolbox sessions to refresh what was presented in our courses or to address a particular topic.
Over 250 project professionals from companies in Qatar and other countries in the region successfully completed the TAFAWOQ programs and four community events were organized. Meanwhile, the first batch of course participants passed the APMP examinations.
Updating the Structural Model on a Mature Carbonate Field With Geosteered Wells: Integrating Well Site Knowledge and Tools Through 2D Structural Well Section Models
Authors: Tawilé E. , Gowardhan M. , Baithotty L. , Moreau O. , Pigeaud T. , Bounoua N. 
Published: December 2015

Extended Abstract
The field is a Cenomanian carbonate reservoir hosted in the Mishrif formation. Its upper reservoirs are made up of stacked, aggrading parasequences of a Rudist platform system. Some of the best reservoir intervals are just a few meters thick, typically three meters, and represent the main targets for infill well drilling . Given their thicknesses and the seismic resolution, none of the thin reservoir layers can be picked on seismic. Typically, only the Top Mishrif erosion can be picked–with, of course, its set of uncertainties–as well as a bottom bounding surface of the upper reservoirs. However, in accordance to the sequence stratigraphy framework, the reservoir layers are relatively isopach at the field scale and can hence be reconstructed through calibration of the well tops during the landing phase of the well. The wells are designed as very long horizontal drains to be geosteered within these thin reservoir layers. The typical length of the geosteered section in these thin reservoirs is of 2000 m for the shortest and up to 5000 m for the longest ones. These wells bring a lot of information related to the field's structure. Indeed, the use of imagery logs, the crossing of faults or bed boundaries and other structural features enable the structure to be constrained along the well trajectory. Moreover, by adding a few hypotheses to the previous elements, it is possible to generate a 2D structural section of the reservoir along the well trajectory. This is what well site geologists in Qatar do on a daily basis when geosteering the well in no more than three meters thick layers.
Integrating Stochastic Seismic Inversion and Classification Results in the Geological Model: a Feasibility Study on an Offshore Carbonate Reservoir
Authors: Tawilé E. , Pernia L. , Ruelland P. , Piazza J-L. 
Published: December 2015

Abstract
The objective of this paper is to present the feasibility study carried out –in a carbonate field context– on the integration of stochastic inversion and classification results in a geological modeling workflow. Indeed the geological model is based on a seven –log defined and core calibrated– electrofacies scheme while the stochastic seismic inversion and classification provides P and S-Impedances (IP & IS), Poisson's ratio (PR) and lithology probability of occurrence cubes. Making the link between lithologies –limestones and dolostones in our case– and the electro facies scheme is the main topic addressed in this feasibility study.
Stimulated Reservoir Volume 101: SRV in a Nutshell
Authors: Vera F. , Shadravan A. 
Published: December 2015

Abstract
During the evolution of technology to successfully produce shale reservoirs, a term called Stimulated Reservoir Volume (SRV) was introduced. Since then, several authors made efforts to identify, characterize or optimize the stimulated reservoir volume. However, as current literature holds, only a few attempts have been made to summarize and analyze all these contributions. The purpose of this work is to discuss SRV, its different concepts and calculation methodologies to diminish the uncertainty and improve the understanding on unconventional hydrocarbon production.
Several techniques are discussed from literature that calculates different volumes, their names and their time-frame scope of analysis that can go from microseismic observation to stimulation to rate transient analysis to numerical simulation. Differentiation between stimulated volume and producing area is also discussed. A discussion over created fractures and the inherited debate over fracture height and brittleness are investigated. Finally, it is reviewed the changes during and after refracturing of maximum horizontal stress, permeability, conductivity and fracture dimensions and it is impact in SRV.
Based data from several hydraulic fractured wells, our observations suggest an effective improvement in the prediction of permeability distribution if more than one SRV concept is applied analyzed at different time intervals. Also results reflects the fact that micro seismic aids SRV characterization as an effective tool. Another observation for improved production is the importance of mobility for shale gas and shale oil that requires creating fracture complexity for the former to be more productive and planar fracture for the latter.
This work delivers a synopsis of several standpoints about Stimulated Reservoir Volume towards a better identification of optimum lateral length location, orientation and proppant volume. This fundamental review will aid reservoir, completion and stimulation engineers on the understanding of the factors that contribute to successful production from unconventional shale reservoirs.
Well Clean-Up Through Topside Production Facilities
Authors: Rondón González Marianna , Kané Moussa , Passade-Boupat Nicolas , Hurtevent Christian 
Published: December 2015

Abstract
In oil industry economic context, the clean-up of wells through surface production facilities is an option in order to minimize environmental impact, economize rig days and commercialize produced clean-up oil. Clean-up operations through offshore topside production facilities started to be performed some years ago. However, many risks must be considered, especially production chemistry risks linked to compatibility between drilling/completion and production fluids. The goal is to ensure process stability and final quality of oil and produced water which, in many cases, must comply with rigorous specifications for coastal discharge or reinjection into the reservoir.
This study shows the methodology developed to evaluate separation and deposits risks. As a general observation, experiments performed show a degradation of the separation process when drilling/completion fluids (completion brines and CaCO3 particles from drilling muds) are added to the emulsion. The most probable hypothesis is that some solid particles will adsorb at the oil-water interface and affect the stability of emulsions. Nevertheless, additives that change the wettability of solids seem to enhance separation, ensuring a separation efficiency equivalent to the system without particles.
In the case of oils that contain very high molecular weight naphthenic acids (TPA), the use of brines with calcium chloride increases the risk of naphthenic salt deposits at topside facilities. The degradation of the water quality was also observed and the optimization of a reverse demulsifier is then required.
The final clean-up strategy should also be adapted to topside design and possibilities to handle drilling fluids. How to separate and recover debris could be a problem for brown fields. For new projects, some additional provisions may be included in the design for well clean-up. In any case, a multidisciplinary risk evaluation is always required to ensure the good progress of this type of operations.
Screening of Polymers for EOR in High Temperature, High Salinity and Carbonate Reservoir Conditions
Authors: Quadri Syed Mohamid Raza , Shoaib Mohammad , AlSumaiti Ali M. , Alhassan Saeed M. 
Published: December 2015

Abstract
Polymer flooding is one of the most attractive chemical EOR techniques for sandstone reservoirs however due to complex geological heterogeneity and harsh reservoir conditions its full potential has not been explored in carbonate reservoirs. The main reason behind this limitation is the inability of conventional EOR polymers like HPAM and Xanthan to withstand these conditions. Candidate polymers must provide the required rheology at minimal polymer concentration, be thermally and mechanically stable, and result in a manageable adsorption on the reservoir formation. A polymer screening study has been conducted on a series of polymers, to identify the most suitable candidate that can tolerate the harsh reservoir conditions. Initially, rheological measurements are conducted on a series of polymers followed by filterability, injectivity, static and dynamic adsorption, mechanical and thermal stability testing as a screening criterion for polymers in EOR operations. Amongst the tested polymers polyacrylamide based co- and ter-polymers showed reasonable temperature stability with low salinity tolerance. Whereas, biopolymer Schizophyllan a polysaccharide showed shear thinning behavior with positive thermal stability and salt tolerance. Long-term thermal stability of biopolymer is also conducted at a temperature of 120 °C and salinity up to 220 g/L under anaerobic conditions for over eight months and no viscosity loss is observed. Biopolymer showed acceptable injectivity on cores of permeability more than 30 mD. Core flood effluents viscosity reached 40% compared to injected sample. In addition the mechanical stability and filterability of biopolymer are also discussed.
Static as well as dynamic adsorptions of biopolymer have also been studied. The static adsorption on four natural minerals (Calcite, Dolomite, Kaolin, and Silica) as well as formation rocks is reported. Out of these four minerals, maximum and minimum adsorption is observed on Dolomite and Kaolin respectively. The adsorption of biopolymer decreases with salinity and temperature. Adsorption on carbonate reservoir rocks is found to be low when compared to pure calcite and dolomite minerals. Dynamic adsorption on cores with different permeabilites (3 to 165 mD) is measured to be low in magnitude (47.5 to 0.53 µg/g).
Embedded Response Surfaces Approach for Uncertainty Quantification
Authors: Busby D. , Chugunova T. 
Published: December 2015

Abstract
Uncertainty quantification on reserves estimation is a fundamental task for project validation on offshore green fields and also for the selection of a development plan that is robust to those uncertainties. To test the robustness of several development plans is then fundamental to be able to evaluate the impact of this uncertainty with low computational cost.
Structural, geological and dynamic uncertainties are integrated in a new workflow based on a set of embedded response surfaces. The first step consists in building an experimental design with only structural and geological parameters to evaluate the impact of such uncertainties on static responses such as oil initially in place. In the second step, this experimental design is completed with additional dynamic parameters. The novelty of the static and dynamic design merging is to incorporate the previously obtained static response surface in addition to the uncertain parameters. By embedding the static response in the variables we obtain a response surface on the reserves more regular and more predictive. In this workflow, mainly applied to green fields, the impact of local geological uncertainty is usually of second order respect to other global uncertainties and it is taken into account as random noise whose variance may depend on the static response.
The method is applied to a real green field with complex multi-level heterogeneities and it is compared to more standard approaches such as Monte Carlo. We manage to obtain a very good response surface quality for the static response (oil in place) that is then embedded in the reserves response surface.
The final accuracy of this response surface is sensibly increased respect to a classical approach considering only static and/or dynamic parameters at minor costs in terms of reservoir simulations.
The new approach reduces sensibly the number of reservoir simulations needed for an accurate uncertainty and risk assessment when applied to select the more robust development plan selected from a set of possible candidates. It also provides useful sensitivity analysis measures to guide possible data acquisition campaign in order to reduce risks and take better decisions.
Karst Paleogeomorphology Reconstruction of Early Ordovician Carbonate Unconformity and its Petroleum Significance, Tazhong Area, Tarim Basin, West China
Authors: Tong Yanming , Zhang Zhenghong , Hauser Ken , Xie En , Yang Pin , Wang Peng 
Published: December 2015

Abstract
Karst carbonate reservoir is playing more and more important role in current petroleum industry, and it is the same in study Tazhong area of middle Tarim basin and even the whole basin. Meanwhile, it is noted that paleogeomorphology of carbonate karst unconformity has obvious control on reservoir development and even hydrocarbon accumulation based on many case studies. Therefore, paleogeomorphology reconstruction is often very fundamental but indispensable study for exploration and production activities in such kind of reservoirs.
The study carbonate unconformity, i.e. the top of Yingshan formation of early Ordovician, typically occurs at burial depth of 5.2~6.5 km, which is almost the same as that of northern Tarim basin, such as Lungu area. However, there are more challenges here in the work of paleogeomorphology reconstruction for Tazhong area when compared to that for northern Tarim basin: 1) the study carbonate unconformity has much lower relief contrast on paleogeomorphologic micro-unit scale, 2) the overlying formation of Lianglitage is carbonate-dominated and contains many reef-shoal intervals (especially for the upper Lianglitage formation), and 3) the current structure of unconformity horizon seems much different from paleogeomorphology surface. These cause that the often-used methods fail, for example, the paleogeomorphology derived from the whole thickness of overlying Lianglitage formation will be distorted because of higher carbonate production rate at some topographic highs, which is different from a normal clastics case where thicker usually means lower and thinner means higher, like the situation in northern Tarim basin.
Expression of the Zagros Orogenic Event in Qatar
Authors: Wright C. E. 
Published: December 2015

AbstractExpression of the Zagros Orogenic Event in QatarThe objective of this paper is to demonstrate the effect of the orogenic events leading up to the main Zagros Orogeny on the stratigraphic succession in Qatar.The full extent of the erosional event was not appreciated by earlier stratigraphers in the region which lead to a plethora of names and a complicated and confused association of stratigraphic relationships. Detailed correlation of well log suites from more current wells across onshore and offshore Qatar has allowed the development of a stratigraphic framework that embodies the work of many earlier stratigraphers and explains some of the challenges faced by them.In Qatar the Coniacian rocks above and the upper Cretaceous rocks below the Late Cenomanian to Cenomanian/Turonian unconformity record the onset and history of the Alpine orogenic events in this region. These events are the start of the collision between the Arabian and Iranian plates and are what we know as the Zagros Orogeny. The Cenomanian/Turonian unconformity represents an hiatus of roughly 9 million years during which over 1,100' of section was removed along the axis of the Qatar Arch. Maximum erosion occurred on the crest of the arch close to the present day Qatari/Iranian border.The stratigraphic scheme is quite simple. Pre-collision tectonic events which heralded the onset of the impending major orogenic event produced unique erosional events within the Mishrif Formation. Erosional wedges within the Mishrif Formation were the result of reactivated structures associated with the Qatar Arch. The application of this new understanding to drilling and seismic interpretation allows us to better understand drilling risks and complex velocity profiles.
Investigating the Role of Ultrasonic Wave Technology as an Asphaltene Flocculation Inhibitor, an Experimental Study
Authors: Amani Mahmood , Retnanto Albertus , AlJuhani Salem , Al-Jubouri Mohammed , Shehada Salem , Yrac Rommel 
Published: December 2015

Abstract
Asphaltenes deposition is one of the common problems encountered in the petroleum industry as it clogs the area near the wellbore, builds up in the well tubing, and precipitates inside separators and other surface facilities. Thus, it restricts the flow of the fluids from the formation to the wellbore and to the surface and, hence, leads to production loss. The remedial measures for asphaltenes deposition, however, cost money and time.
The aim of the study presented in this paper was to experimentally investigate the role of ultrasonic wave technology as an asphaltenes flocculation inhibitor and to quantify the actual reduction in asphaltenes content of the crude oil when ultrasonic waves were applied. For these purposes, sonication experiments, viscosity measurements, and asphaltenes extraction experiments were performed. Moreover, this study aimed to verify the results and the conclusions that were achieved in a previous similar work by repeating some of the methods they used with different crude oil sample.
Conducting this experimental study led to the conclusions that ultrasonic waves have the ability to break down asphaltenes conglomerates and, hence, reduce asphaltenes content in crude oil samples and that there is an optimum time for sonication at which highest asphaltenes particles disintegration is achieved. Moreover, it was concluded that the crude oil viscosity is influenced by its asphaltenes content.
Correlative XRM and FIB-SEM for (Non)Organic Pore Network Modeling in Woodford Shale Rock Matrix
Authors: Goral Jan , Miskovic Ilija , Gelb Jeff , Andrew Matthew 
Published: December 2015

Typical shales are characterized by their small pores and their very low porosity and permeability, hence making these rocks challenging in obtaining economically viable gas and/or oil. A considerable amount of effort has gone into measuring and characterizing the pore volume both within organic matter and mineral shale rock matrix, and investigating which pores really contribute to these petroleum systems. Therefore, quantifying the amount, size distribution and connectivity of pores within shale reservoirs is at the heart of both production and storage issues.
A new holistic approach for characterization of nanoscopic scale structural heterogeneity in shale, presented here, couples micro and nano X-ray microscopy (micro- and nano-XRM) with focused ion beam scanning electron microscopy (FIB-SEM). This integrated approach provides a unique opportunity to characterize in great detail the complex three-dimensional (3D) microstructure of shale over multiple length scales, from the centimeter length scale to the single nanometers. To explore the practical significance and reach of this newly developed analytical framework, a shale specimen from the Woodford formation was imaged several times with non-destructive XRM at successively higher resolutions, and then finally imaged with the ultra-high-resolution by destructive FIB-SEM serial sectioning. Further to the imaging, the organic- and nonorganic-matter-related pore networks within Woodford Shale matrix were extracted using the FIB-SEM images, in order to quantify the evolution of porosity associated with both organic and nonorganic matter.
The findings indicated that the organic-matter-related pore network strongly dominates over the nonorganic-matter-related pore network within the investigated specimen, suggesting a strong relationship between porosity and organic content.
Challenges and Opportunities of Modelling Long Horizontal Wells. A Case History
Authors: Arata F. , Cardola P. , Costanzo C. , Grilli F. , Valdisturlo A. , Burt J. , Chinellato F. , Denichou J. 
Published: December 2015

Abstract
Nikaitchuq is an oil field on the North Slope of Alaska that has been developed with more than 60 extended-reach wells having 6,000-ft to 18,000-ft-long horizontal sections. The main reservoir interval in Nikaitchuq corresponds to a shelfal lobe composed of two main sand bodies, encased in structural depressions. The development scheme consists of waterflood line drive with horizontal producers and water injection wells located side by side. The majority of the development wells were designed with a single horizontal trajectory undulating between the two main sands bodies in counter phase with the related water injectors.
To be successful, such challenging well design requires accurate geological modeling, effective geosteering capabilities, and sensible well data acquisition. The objective of the approach here described is to correctly reconstruct the reservoir geometry by integrating numerous data and information coming from such long horizontal wells. However, data and information that have originated from different sources have different levels of accuracy. A thorough data quality assessment is a mandatory step in any data integration exercise. Hence, all information available in each horizontalwell section was reviewed in detail and cross-examined. Bed boundary mapping data interpretation via different inversion processes and log and image interpretations (such as gamma ray, neutron density, resistivity, density images, deep azimuthal electromagnetic data) were compared, validated, and integrated in the 3D geological model to perform a very precise reconstruction of reservoir internal geometry.
Such accuracy in modeling was not only aimed at enhancing the precision of volumes in place and resource estimates, but it was also a prerequisite for the successful drilling of the subsequent wells during the field development.
The novelty of the approach consisted in the integration of density image logs, bed boundary mapping data, and resistivity modeling results to derive accurate information on the reservoir geometry at a scale useful for 3D modeling. This use of data goes beyond common practices.