bluuebunny/crossref_metadata_2025_split huggingface dataset:
Surface Development Aspects of Alkali-Surfactant-Polymer (ASP) Flooding
Authors: Weatherill Alan 
Published: March 2015

Abstract
This paper highlights the differences between an Alkali-Surfactant-Polymer (ASP) Flood project and traditional Exploration and Production (E+P) developments from an Engineering and Operations perspective. It lists the common problems encountered, drawing on published and unpublished sources, and describes their root causes. It proposes strategies for avoiding the problems in future ASP flood applications.

Introduction
A number of Shell-affiliated operating companies have identified Enhanced Oil Recovery by chemical injection as an option for accessing the remaining oil in place and extending field life. Several pilots have been implemented and more are under development. Currently the most advanced of these is a full-scale Polymer Flood that will soon start in Marmul in the Sultanate of Oman.
In general these companies are working to meet the challenges typical of late-life field production, namely: handling increasing water production, minimizing chemical usage, prioritizing well interventions, optimizing equipment maintenance strategies and assuring technical integrity and plant availability. The organisation and the skill set of the staff running these fields reflect this focus.
Implementing a chemical flood requires special skills and a different focus. The project is somewhat experimental because of the unknowns about how the chemicals will behave in the reservoir. The process line-up and equipment list include items not seen in a typical Exploration and Production company. The standard of cleanliness and the degree of sampling and monitoring are more like those seen in a specialty chemicals or food processing plant. This paper summarizes what is different about chemical EOR for the surface engineering and operations team and it provides an overview of the skills and the team culture needed to succeed.
What is ASP flooding?
This paper considers Alkali-Surfactant-Polymer (ASP) flooding, as this encompasses a broad range of chemicals and technologies. Most of the challenges associated with, for example, polymer flooding, are a subset of those for ASP flooding. In an ASP flood, a series of chemical slugs sweeps the reservoir from injection wells to producing wells. The sequence of injection is:Softened water. This provides a buffer in the reservoir between the existing water (which, in late field life, will be a mixture of connate water and water flood water) and the following ASP slug. Generally this existing water is hard and without this buffer the Alkali in the ASP slug would precipitate the divalent ions as scale. These divalents also precipitate the surfactant, which is usually anionic, and interact with polymer to reduce its viscosity.
Fast track lithological interpretations applied to detailed evaluation of Norwegian Sea basin
Authors: Vernay Paul , Mathieu Jean Philippe , Leduc Jean Pierre , Martinez Lionel , Bastien-Dubes Alice , Fourmentraux Philippe 
Published: March 2015

Abstract
Geopetroleum studies, assessment of operated or non -operated acreages, and evaluation of new opportunities use correlation sheets and facies distribution maps. These documents are elaborated from lithological interpretations based on conventional logs (gamma ray, density, neutron, sonic, resistivity). The main challenge the geologists can face is to interpret huge intervals covered by heterogeneous log data in numerous wells in a very short space of time. Currently available software packages cannot be used as they lack the tools required to automatically analyze, standardize and process simultaneously all the wells. Interpretations are usually carried out on a small number of selected wells, which are processed one after the other. A leading edge methodology supported by dedicated software tools is presented here. It is composed of five steps: harmonization of log names, units and sampling rates; cleaning of logs; multi-well pre-processing; faciological modelling; multi-well quality control and facies maps creation. It was developed to process consistently all the available data sets and obtain homogeneous and reliable lithological evaluations in a shorter time. The interest in the implementation of such a method is illustrated from the example of a petroleum synthesis which was realized on 160 wells in the mid Norway Haltenbanken-Dønna Terrace areas. This method and the associated statistical tools have been also successfully applied in many other petroleum contexts and many geographical areas including the Middle-East. The use of all available logs improves the quality of the results and assures homogeneous interpretations. A significant reduction in costs and durations is observed in all the studies that have applied this methodology. This positive effect increases with the size of the well data base to be processed. Typical reduction factors from 3 to 10 are experienced. In addition, studies that would be prohibitively long and expensive with classical methods become possible.
Reservoir Development Modeling Using Full Physics And Proxy Simulations
Authors: Yang Yahan , Davidson Jeffrey Edward , Fenter David James , Ozen Ozgur , Boyett Barbara A. 
Published: March 2015

Abstract
This paper describes a modeling technique for reservoir development using full physics and proxy simulations. Traditionally, full physics simulation involves gridding and discretization, fluid property calculations, displacement modeling, assembling matrix equations, and solving the equations over time. In the gridding step, the reservoir is divided into a collection of cells on which the governing equations for multiphase flow are rewritten in discrete form. Fluid property and displacement modules compute various quantities and their derivatives needed for assembling the matrix equations during time stepping. For reservoir simulation, the system of matrix equations often is quite large and may contain hundreds of thousands of unknown variables. Solving such a system is a computationally intensive task. As a result, a simulation run may take days or even weeks for large models to complete. To improve the computational time, proxy simulations have been considered in recent years as an alternative to full-physics simulation. In general, proxy simulations achieve higher computational efficiency at the expense of accuracy, and are constructed by either reducing the model size or simplifying the physical behavior of fluid flows.
In this work, we combine full physics and proxy simulations to take advantage of the strength of each approach. The proxy technique employed is known as profile generator. It simplifies the reservoir into material balance tanks and well source/sink terms into a set of tables known as type curves, which relates production GOR, WCUT, etc. to EUR and other parameters. With full physics or proxy simulation, flows in wells and surface facilities can be modeled and production/injection rates allocated using rule-based or optimization-based well management.
Integration of grid-based simulation and profile generator in a single modeling system makes it possible to easily generate type curves and validate results from proxy simulations. For large assets containing multiple reservoir systems or fields, this technique allows engineers to build a mixed simulation project containing grid-based models for some reservoir systems and type curve-based models for the rest, thus obtaining a balance between accuracy and computational efficiency. Using this new technique, engineers are able to more efficiently evaluate facility constraints and facility upgrade options, quantify impact of changing a field's startup time on facility capacity, and optimize production from multiple fields.
First Australasian Batch Conductor Drilling - World Record Size - Ahead of Time Estimate
Authors: Niedermayr Michael , Pearse Jack , Tan Ming Zo , Utama Budi 
Published: March 2015

Abstract
Since the turn of the millennium, non-retrievable drilling with casing technology has been introduced to the Asia Pacific region. Soft formations encountered in offshore drilling environments have promoted the successful application of casing drilling technology for conductor and surface casing installation1,2,3.
The Weatherford system employs a simple aluminium based casing drill shoe and float collar assembly, driven by a surface drive system that transmit torque from the top drive to the casing string4. Upon reaching targeted casing shoe depth, the cementing operation can commence almost immediately. The next conventional drilling assembly can then drill out the casing drilling assembly using a traditional PDC or rock bit without requirement for a special drill-out bit.
The Maari Development Project in New Zealand is situated in an ideal soft drilling environment that is within the capability of the drillable drill shoe. During the project planning stage, non-retrievable drilling with casing technology was highlighted as a viable technology to improve drilling efficiency, reduce cementing times, protect the weak shallow formations the platform foundation depends on, and reduce potential risks. Substantial engineering effort and time have been invested to tackle all relevant technical issues.
This paper presents the Maari Project's 24" conductor drilling programme, covering the entire process from the planning stage through to the execution, which resulted in successfully installing and cementing nine strings of 24" conductor ahead of the time allocated to conventionally drill, case, and cement eight strings.

Background
The Maari oil field in permit area PMP 38160 was discovered in 1983. Through various acquisitions PMP 38160 is now operated by OMV New Zealand Limited (69%) on behalf of its joint venture partners Todd Maari Limited (16%), Horizon Oil International Limited (10%), and Cue Taranaki Pty Ltd (5%). The permit contains the Maari discovery and is located close to another oil discovery the Manaia field in block PEP 38413.
Five production and three injector wells were planned for the initial development. In addition, provision was made for the construction of a further 4 wells at a later stage in Project life. All these wells can be drilled from or tied back to the wellhead platform (WHP) "Tiro Tiro Moana", which is equipped with 12 drilling slots. The waxy nature of the crude requires heating downhole, on the wellhead platform as well as the FPSO "Raroa" to successfully transport the crude.
Fluid Characterization and Modeling of Compositional Variation, Dukhan Field, Qatar
Authors: Gupta Deepak K. , Lawrence John , Abdul Majid Mohamed Naguib , Wahlheim Thomas A. 
Published: March 2015

Abstract
The paper describes the development of an equation of state (EoS) for two reservoirs of the Dukhan field, the Arab C and the Arab D reservoirs. The paper also describes the development of compositional maps for both the reservoirs. In absence of pre-production samples, an iterative approach was used to estimate composition at a known depth for the Arab C reservoir. Equilibrium contact mixing (ECM) method along with an iterative approach was used to estimate oil composition at the gasoil contact depth for the Arab D reservoir. By examining the heptanes-plus (C7+) properties of the samples collected from the depleted Arab C reservoir, existence of compositional gradient in the reservoir at discovery conditions was confirmed. It was shown that the existence of near constant C7+ properties in the oil-column of the depleted Arab D reservoir does not preclude the existence of compositional gradient at discovery conditions. By incorporating the gravity segregation and the thermal diffusion effects, oil composition maps for the Arab C and the Arab D (excluding Diyab sector) were developed. It was shown that the inclusion of thermal diffusion effect resulted in very small changes in component concentration for the Arab C reservoir. The large saturation pressure difference between three sectors of the Arab D and the fourth sector, Diyab was then modeled using molecular diffusion. For the Arab D gas-cap, the gas composition at the gas-oil contact depth was calculated by utilizing the tuned EoS and the oil composition at the gas-oil contact. The gravity segregation and the thermal diffusion significantly changed pentanes-plus (C5+) and C7+ distribution in the gas-cap gas with 23% and 30% reduction in mole% from the gas-oil contact to the crest of the structure.

Introduction
The large, mature Dukhan Field is located onshore Qatar, approximately 80km west of Doha. It is a North-South plunging anticline approximately 70km long by 8km wide (Figure 1)1. The field was discovered in 1939 and first production occurred in 1949. The field has more than 750 well penetrations. The major oil reservoirs are the Upper Jurassic Arab C and Arab D. There are lesser amounts of oil and gas in the Middle Jurassic and non-associated gas in the Permo-Triassic Khuff formation.
An Integrated System for Pipeline Condition Monitoring
Authors: Strong Andrew Peter , Lees Gareth , Hartog Arthur H. , Twohig Richard , Kader Kamal , Hilton Graeme , Mullens Stephen , Khlybov Artem , Sanderson Norman 
Published: March 2015

ABSTRACT
Pipelines are at risk from external threats including third-party intrusion, societal development and ground movement in addition to the ongoing potential for leaks due to corrosion or other causes. Although the appropriate use of internal inspection practices and regular survey of coating and cathodic protection systems will give timely information on any deterioration in pipeline condition, external threats can be unpredictable.
In this paper we present the unique and innovative pipeline and flowline integrity monitoring system developed by Schlumberger in collaboration with BP. The system uses optical fiber distributed sensors to provide continuous, simultaneous distributed measurements of temperature, strain and vibration for the detection, monitoring, and location of events including:•Third-Party Interference (TPI), including multiple simultaneous disturbances•Geo-hazards for example landslides or subsidence•Gas and oil leaks•Permafrost protection
Optical fiber sensors are widely used and have over the past 20+ years built a track record in the Oil & Gas industry in applications including pipeline condition & leak monitoring, optimization of oil well productivity and LNG plant leak detection and cool-down process monitoring.
The solution provides a unique and proactive approach to pipeline integrity management. It performs analysis of a combination of measurands to provide the pipeline operator with an event recognition and location capability, in effect providing a hazard warning system, and offering the operator the potential to take early action to prevent loss.
Through the use of remote, optically powered amplification, an unprecedented detection range of 100 km is possible without the need for any electronics and therefore remote power along the pipeline. A system can thus monitor 200 km of pipeline when configured to monitor 100 km upstream and downstream from a single location.
Experience in Low-Frequency Spectral Analysis of Passive Seismic Data in Volga-Ural Oil-Bearing Province
Authors: Birialtsev Evgeny , Eronina Ekaterina , Rizhov Dmitriy , Rizhov Vasiliy , Shabalin Nicolay , Vildanov Alik 
Published: March 2015

Abstract
In this paper, we consider our experience with passive low-frequency seismic exploration for oil and gas. We present the data on the phenomenology of the effect, sets out possible geophysical mechanisms of effect, present results of numerical simulations in comparison with the observed results; we describe the main approaches to the interpretation of seismic data studies and give a brief overview of geological results of our microseisms research in the Volga-Ural oil province.

Introduction
Geological exploration in areas of old oilfields such as field Romashkino in the territory of the Republic of Tatarstan has a number of features (Mouslimov et al., 2007). Targets of geological exploration are predominantly the exploration of small fields and exploration of producing fields in the boundary zones. These objects are characterized by complex geological structure, structural traps have a small amplitude, small size, have numerous complications such as lithological replacement and tectonic faults.
Under these conditions, the effectiveness of structural seismic studies was decreases. Combination of structural seismic method and methods of local prognosis of oil-bearing is necessary to improve the efficiency of drilling. However, traditional non-seismic methods - high-precision gravimetric, electrical, geochemical studies have sufficiently large radius of the study and also not effective for small search objects.
The method of passive seismic ANCHAR (Aroutyunov et al., 2001) was tested in 2002 in the Republic of Tatarstan as a method of local prognosis of oil-bearing for solve this problem. According to this method in the spectrum of microseisms over natural gas and oil deposits should be observed pronounced spectral maxima in the range of 1–10 Hz. Work was carried out in two areas and have produced mixed results. On the one hand, the predictions of oil-bearing by this method have the conflict with the existing ideas about the geological structure and the drilling has not been undertaken for this predictions. On the other hand - microseismic noise over oil deposits and outside them had obvious differences. Mixed results and the need for an effective method of local prediction led to a large complex of experimental and theoretical studies of the structure microseismic field as a possible indicator of oil saturation. In this report we present the results of science research and practical application of passive microseismic research to address the various geological problems of Petroleum Geology.
Structural Control on Permo-Triassic Deposition in the Central Arabian Plate: a Multi-Scale Approach.
Authors: Zampetti Valentina , Borkhataria Ravi , Koopman Anton , Vroon Marietta , van Oosterhout Cees 
Published: March 2015

Abstract
A multi-scale analysis integrating structural concepts, local seismic data and well correlations across the Central Arabian Plate demonstrates that the thickness and facies distributions of one of the most important hydrocarbon reservoirs in the Middle East, the Khuff carbonate, are strongly controlled not only by the structural relief at time of deposition but also by the reactivation of the basement structural fabric related to Permo-Triassic tectonic events.
Stratigraphic and sedimentological data indicate that on a regional scale, the Khuff carbonate shows a wide variety of depositional environments (with facies ranging from coastal plain anhydritic claystone, tidal flat/lowto-high energy lagoonal deposits to open-marine dolostones alternating with grainy limestones and high-energy shoal-dominated dolostone/thick grainy limestones) and thicknesses (from near zero at the pinch-out of siliciclastic facies in central Saudi Arabia, to more than 400 m (1300 ft) in the Ghawar field in northern Saudi Arabia, expanding to 800 m (2600 ft) in the North field, Qatar and to nearly 1000 m (3300 ft) in the eastern United Arab Emirates).
Pre-Khuff basement-related anisotropies on the Arabian Peninsula are interpreted to have formed as early as Late Neo-Proterozoic to Ediacarian time and to follow three main trends: N-S (Nabitah),NW-SE to WNW-ESE (Najd),NNW-SSE to NW-SE (Mesopotamian).
Leveraging a Common Infrastructure to Support Qatar's Rapid LNG Expansion
Authors: Al-Amoodi Ahmed , Felton Keith C. , Kasim Kamal 
Published: March 2015

Abstract
The State of Qatar is rapidly expanding to capture almost one-third of the world's LNG market. By 2010, LNG exports from the State of Qatar are projected to reach 77 million tonnes per annum. In addition to the LNG production, there will be a sizeable quantity of by-products - condensate, propane, butane, and sulfur - as a result of the LNG production. These by-products are expected to reach production rates of approximately 80,000 m3per day (500,000 barrels per day) of condensate, 20,000 tonnes per day of propane, 13,000 tonnes per day of butane, and 12,000 tonnes per day of sulfur.
To support this expansion, the State of Qatar has embarked on a pioneering approach to the storage and loading of LNG as well as its by-products that will serve as an example of significant capital investment savings, operational flexibility, and reduced land requirements. Traditionally, dedicated storage and loading facilities (infrastructure) have been designed and built to support a specific LNG production train and its associated by-products. The State of Qatar's innovative approach has been the design and construction of a fully integrated common infrastructure to support all of the joint venture owned LNG production trains as well as other gas related projects in Ras Laffan Industrial City. This paper will describe the unique aspects of this fully integrated infrastructure, its benefits, and the complexities and challenges associated with making the vision of a fully integrated LNG infrastructure come to fruition.
Optimal Well Placement In Long Horizontal Developments: Al Khalij Case
Authors: Meyer Nicolas Etienne , Socquet Juglard Florian , Dehesdin Remi , Narayanan Ramdas 
Published: March 2015

Abstract
When drilling horizontal drains in a thin layer environment, one of the main challenges is to maximise the reservoir exposure, which means remaining in the pay zone as long as possible and at the same time avoiding or at least identifying any possible water conductive events. Considering that an angular difference of only one degree between the well bore axis and the apparent dip of the formation along the well path results in about half a metre vertical shift every drilled stand, remaining within a one or two metres thick reservoir requires a better precision for an optimal reactivity in the geosteering process.
The first requirement in this type of application is an accurate geological model that ideally features the layer geometry as well as the distribution of reservoir characteristics such as resistivity, porosity, radioactivity, saturation… etc. A good knowledge of the structural scheme is necessary, including fault frequency with the order of magnitude of their vertical throw, the frequency of structural undulations with an idea of their wavelength… In addition, it is necessary to visualise in real time the well within the model. Then, it becomes possible to anticipate possible structural undulations and to pro-actively make the necessary decisions to properly steer the drain within the reservoir.
The industry proposes two types of LWD resistivity imaging tools which may be considered for this purpose:• The azimuthal electromagnetic propagation resistivity imagers,• The laterolog type resistivity borehole imagers
The laterolog type resistivity imagers have the essential drawback that they only work in conductive mud systems. But on the other hand, they are able to provide very high resolution images. This enables the accurate picking of sedimentary and structural events such as bedding, dips and fractures.
Al Khalij field, offshore Qatar, features a carbonate layer-cake of alternating oil bearing and water bearing limestone reservoirs. Each oil bearing reservoir layer is about 2m to 5m in thickness. Surrounding water-bearing layers show similar porosity values but much finer grain size and have no physical limits with oil bearing reservoirs. The present paper describes an integrated method developed to achieve an efficient geosteering of long horizontal drains which may reach 3,000m to 4500m in order to maximise the reservoir exposure along the well path.