bluuebunny/crossref_metadata_2025 huggingface dataset:
Advances in Wireline Conveyed In-situ Reservoir Stress Testing Measurements: Case Studies from the Sultanate of Oman
Authors: Cig Koksal , Al Mandhari Alyaqdhan Sulaiman , Elmsallati Salem Mohamed , Qobi Latifa
Published: May 2016

In-situ reservoir stress measurements are essential input to a wide variety of the production and injection applications of reservoirs. Most of the reservoirs in this article require water injection to maximize recovery without breaking the matrices unintentionally. In some cases, it is also important to create a controlled fracture growth in a formation unit without breaking bordering barriers or zones. The main purpose of the in-situ reservoir stress testing of the case studies in this article is to calculate the minimum stress to improve the reservoir management plans for well placement, production, injection and fracturing processes.

One approach of measuring stresses in many zones is to use the wireline conveyed stress testing tools. The wireline conveyed in-situ reservoir stress testing measurements are frequently performed in the Sultanate of Oman for a wide range of operational and geomechanics applications such as but not limited to:Hydraulic fracturingFracture growth/containment issuesPolymer injectionBorehole stabilitySand production predictionStress evolution with depletion, hot and cold injection

The stress testing zones vary from tight to high permeable zones as well as shale zones. The complexity and wide variety of the stress testing applications inevitably led modifications and improvements on the wireline conveyed stress testing tools. These improvements mainly are various types of pumps, higher performance dual packers and mandrels, innovative stress testing methods. The latest improvements and methods in stress testing help addressing the broader range of formations (deep and shallow, tight and permeable) in an extensive type of wells from vertical or deviated to horizontal.

In this article, the examples of several unique stress testing applications are presented. Shale stress testing with a viscous fluid, horizontal well stress testing, tight and very high permeability formation stress testing, sleeve fracturing stress testing methods are discussed in details.

Introduction

In-situ stress magnitude and direction measurements in vertical and lateral directions are required in a reservoir for several reasons. These are for hydraulic fracture design, fracture type identification, water and gas injection management, fault activity, wellbore stability, sand production, rock mechanical properties, casing strings design, cap and base rock integrity, subsidence, and gas storage design.
A Consistent Workflow From Seismic Acquistion to Well Positioning - For Challenging Data in Block 11, Offshore Qatar
Authors: Hanitzsch C. , Bresser G. , Heerde W. , Jakob V. , Suess M.P. , Zahran M.E. , Altenkirch J.
Published: May 2016

This paper describes the seismic workflow for exploration in Block 11, offshore Qatar, from the decision to acquire a 3D seismic survey, via processing, interpretation, time/depth conversion and reservoir characterization to positioning of wells. The area is generally very flat in the morphology of the horizons and the targets are relatively shallow, therefore, the decision for acquiring 3D seismic data had been taken rather late. It turned out to be a textbook example why 3D seismic is imperative even in such generally flat areas. The structural history of the area, from the old basement lineaments up to the earliest Cretaceous-Tertiary aged reactivation movements, could be outlined by 3D seismic data and it shows a very complex structural pattern.

Introduction

Early 2007, Wintershall Holding AG acquired a 3D seismic survey in Block 11, offshore Qatar. The area is generally very flat in the morphology of the horizons and the targets are relatively shallow, therefore, the use of 2D seismic had been considered as appropriate in the past. However, after several wells - including a discovery and another well with poor depth prediction, it had been decided to acquire the before mentioned 3D seismic survey with the following objectives:to get a consistent 3D high quality volume allowing a continuous interpretation of geological horizons and faults,to get a seismic velocity model suited for more accurate time/depth conversion, andto get better understanding of compartments and fault patterns, that will allow a better understanding of hydrocarbon migration path ways and seal failure risk,to get seismic data suited for state of the art technologies, like seismic reservoir characterization,to assess leads and prospects, and to define future drilling locations.

Most precise velocities are of particular importance, because the overburden shows significant lateral velocity changes that cause important differences between time and depth maps. Depth structures are not necessarily visible on time maps, and apparent time structures are not necessarily existent in depth.
Plant Performance Monitoring: Improving Surveillance of Rotating Equipment on a Gas Processing Plant
Authors: Boero-Rollo Jean-Gregoire , Galtie Bernard , Tincelin Pierre-henry , Kessler Nicolas , Lacoux Xavier
Published: May 2016

Capitalizing on early successes in advanced well control and real-time monitoring, Total has engaged in a major "Digital Field" initiative aimed at developing real-time asset management. Combining both proven and leading-edge technologies such as real-time databases, web services, business orchestration and a distributed asset model, the Field Monitoring template proves to be a powerful tool to improve global asset management and optimize the oil and gas production chain, from reservoir to export facilities. The field monitoring solution is being implemented as a set of independent yet integrated modules. This paper presents the concept of one of the modules, the Plant Performance Monitoring (PPM) module, a real-time remote monitoring system dedicated to surface facilities. It presents and discusses early results of a pilot application to surveil major rotating equipments at a 520 mmscfd gas processing plant located on the Tierra del Fuego site in Argentina.

The objectives of the pilot are as follows:The primary objective of the pilot is to demonstrate a near real-time tool that provides advance notices on abnormal plant trip.To provide plant staff with quantitative Key Performance Indicators (KPI) such as efficiency, machine availability and utility consumption.To allow proactive maintenance, most particularly, to anticipate the effects of operational changes on assets.To provide cause and effect analysis using near real-time information available from separate components such as vibration monitoring systems, process data historians …

The PPM-Rotating Equipment (PPM-RE) application integrates online process simulations which provide new insights in terms of conditional maintenance and actual production potential or constraints. After several months of operations, The PPM-RE pilot has demonstrated its ability in improving diagnosis and decision-making through prompt collaboration between Cañadon Alfa site and Buenos-Aires (local headquarters several thousands kilometres away). Such an application can also allow the difficult-to-troubleshoot cases to benefit from the TOTAL headquarters and research centers anywhere in the world.
The Application of In-fissure Divert Fracturing Technology in Ultra-low Permeability Oil Field
Authors: Song Zhenyun , Wang Xiaowen , Ren Yanpeng , Li Yong , Zheng Weishi
Published: May 2016

According to the geologic characteristic and development, performance of ultra-low permeability reservoirs, and oil-water distribution rules of reservoir, this paper puts forward the key points in improving the single well production of old oilfield—develop the "dead oil area", and forms supporting technologies of in-fissure divert fracturing which is suitable for ultra-low permeability reservoirs. The onsite experiments prove that the in-fissure divert fracturing technology can effectively improve old well production of ultra-low permeability reservoirs.

Introduction

Changqing oilfield is a typical low-permeability, low pressure, low-production reservoir. Water flood and fracturing are indispensable measures to improve single well production. With the deepening of oil field development, oil production continues to decline, water content increases, the oil field development problems are conspicuous. There are a large number of "dead oil area", and the oil-water relationship is complex. The conventional refracturing measures cannot develop the "dead oil area". The cost is high, but the economic effects are limited. Therefore, in-fissure divert fracturing technology is developed and applied. This technology has been applied in 700 wells and has effectively developed "dead oil area" and improved well production.

The necessity analysis of fracture reorientation in ultra-low permeability oil reservoir

Geological characteristics.

CI and CII oil layer of Triassic YI group is one of the mainly developed reservoirs for Changqing oilfield. Reservoir lithology is mainly arcose, which is a typical ultra-low premeability, low pressure, and low production reservoir. (See Table 1)
Meeting The Challenge Of Global Climate Change With Technology Innovation
Authors: Yang Yan , He Yan Qing , Rao Libo , Wang Jingmei
Published: May 2016

Global climate change is one of the serious problems faced by humankind in the 21st century. Developing policies and practices that tackle climate change without removing opportunities for growth and development has become one of the most significant challenges for governments and industry. The oil companies may contribute to the greenhouse gas control by developing low carbon energy, capturing, utilizing and storing carbon dioxide, continuously improving the energy efficiency and providing efficient products. To realize the greenhouse gas control goal, the need for technological innovation is dramatic and increasing. The companies are suggested to manage the relavant technologies in a strategic way, care and participate in the policy making and join the international network to accelerate the innovation process. The strategy, practice and technological innovation cases of CNPC in greenhouse gas control are introduced.

The challenge of global climate change

Global climate change is one of the serious problems faced by humankind in the 21st century. In particular, with increasing growth of fossil fuel (such as coal and oil) consumption, the emission of greenhouse gas (such as CO2) has kept growing.

According to the WEO (world energy outlook) 2008, in the Reference Scenario, rising global fossil-fuel use will continue to drive up energy-related CO2 emissions, from 28 Gt in 2006 to 41 Gt in 2020 - an increase of 45%. The Reference Scenario trends in world energy use put the world on course for the concentration of carbon dioxide (CO2) in the atmosphere to double from 380 parts per million in 2005 to around 700 ppm in the next century. Taking into account all greenhouse gases in all sectors, this would lead to a CO2-equivalent (CO2-eq) concentration of around 1 000 ppm, corresponding to a rise in global average temperature of up to 6°C, relative to pre-industrial levels.

There is a growing scientific consensus that anthropogenic greenhouse gases are driving detrimental climate change. If GHG emissions are not reduced to significantly below current levels within the next few decades, there will be further warming and sea-level rise for centuries to come. This will result in adverse impacts on human health, natural ecosystems, and the economy. Co-ordinated action is needed urgently to put the world on a different emissions trajectory (figure 1).
Quantifying the Value of a Future Pressure Transient Well Test with Reservoir and Measurement Uncertainty
Authors: Prange Michael , Bailey William John , Kuchuk Fikri J.
Published: May 2016

We present a consistent and functional methodology for conducting value-of-information (VoI) analysis on proposed well tests in the presence of multiple critical uncertainties associated with the reservoir and the measurement/interpretation. Such uncertainties can impact asset economics acutely when they influence recoverable hydrocarbons. A key feature of this analysis is that the value of the measurement is determined before the measurement is made. Our demonstration uses an example of a marginal offshore asset where severe compartmentalization is possible. In this example, the VoI is a critical deciding factor because it is not obvious a priori that this value will justify the cost of the test in this marginal asset.

Our analysis uses a novel approach to standard decision trees by introducing new decision tree nodes in the form of "uncertainty" and "transformation uncertainty" nodes that can accommodate single or numerous continuous and discrete uncertainties. Without such novel tree components, a standard decision tree would become far too cumbersome for practical purposes and may even result in sub-optimal (uneconomic) development decisions from being made because of the discretized nature of the existing decision tree constructs.

We also consider, in addition to the reservoir uncertainties, the uncertainty in the well test measurement and/or the interpretation itself. We present expected asset net present value as a function of measurement uncertainty. Since well-test uncertainty can be related to the well-test duration, we show how the optimum well-test duration can be determined by identifying the time at which the difference between VoI and test cost is maximized. The cost of running the test longer than this optimal duration will only serve to reduce the net present value of the asset.

Introduction

The problem of establishing meaningful value-of-information (VoI) metrics for a well test when faced with multiple significant uncertainties is examined. Such uncertainties can impact asset economics acutely when they influence recoverable hydrocarbons. We examine this VoI through an example of a small, marginal, offshore asset where the primary reservoir uncertainties relate to the degree of possible compartmentalization as well as permeability and porosity. The underlying driver of this study was to devise and test a consistent and functional methodology that can compute meaningful VoI for a well test such that all significant uncertainties are considered, including measurement uncertainty.
Dukhan 3D: An Ultra High Density, Full Wide Azimuth Seismic Survey for the Future
Authors: Seeni Salva R. , Robinson Scott , Denis Michel , Sauzedde Patrick
Published: May 2016

This paper presents a case study on the logistics and acquisition of a large, ultra high density and full wide azimuth 3D seismic survey across the Dukhan field for Qatar Petroleum (QP), Figure 1. This survey represents a step change in seismic data acquisition providing greatly enhanced data quality by full wide azimuth and very dense spatial sampling complemented by good quality uphole and simultaneous 3D Vertical Seismic Profile (VSP) recording. It is expected that this survey will set an industry standard for seismic acquisition leading to improved field redevelopment. While the 3D seismic data can always be re-processed in the future, it is possible that future re-acquisition of the entire Dukhan field area may be difficult or impossible to justify. Therefore one of the key driving principles behind the survey design was to ensure that QP did not under specify the source and receiver effort so that it represented a "no regrets" case for the future.

There are several key operational elements to this survey, the complexity of terrain which varies from sand, rock and sabkha to marine transition, busy infrastructure both residential and industrial i.e. townships, QP's oilfield installations and thirdparty quarries and factories. All of these operational elements must be managed successfully to achieve QP's technical objectives for high quality seismic data.

Introduction

The Dukhan field is a major oil field in Qatar discovered in 1939; it contains more than 350 wells producing from 4 major reservoirs. It has a complex history of production & development strategies, starting with natural pressure depletion for more than 20 years, followed by power water injection since 1989 and gas cap cycling since 1998. As with other large mature Middle East oil fields, Dukhan has also witnessed significant changes in technology over the last 60 years. In order to maximize the long term economic recovery from the field, QP is committed to applying leading edge but fit-for-purpose technologies. New, state of the art, 3D seismic data providing updated reservoir models will enable QP to continue the development of Dukhan field for many years to come.
Hydrydrocarbon Generetion & Natural Gas Accumulation In The Southern Margin Of Junggar Basin
Authors: Yang Haibo , Changyong Zhao , Yanping Qi
Published: May 2016

1. In the southern margin area, four sets of source rocks including Permian, Jurassic, Cretaceous and Tertiary source rocks are developed, and their distributions and maturities are very different.

In the southern margin of Junggar Basin(mainly in the western section of the southern edge), four sets of source rocks including Permian, Jurassic, Cretaceous and Tertiary source rocks are developed. Permian and Jurassic source rocks are basically located at the southern edge of the region; Cretaceous source rocks are mainly located in the Huo- Tu - Ma region; Tertiary source rocks are mainly located in the vicinity of Sikeshu area.

The four sets of source rocks at the southern edge of the region have hydrocarbon potential. The abundance of organic matter in Permian and Lower Jurassic source rocks is higher, and the organic matter types are mainly type ?, the abundance of organic matter in Cretaceous and Tertiary source rocks is slightly lower but the organic types are better which are dominated by type?and type?. Permian source rocks are at the mature-high mature stage in this region; Jurassic source rocks are in a low-mature-high mature stage; Cretaceous source rocks is in immature- mature stage, but the Cretaceous source rocks in Wusu-Changji area are in the peak of oil generation; Tertiary source rocks of most region is in immature-low mature stage, but the source rocks reached a mature stage in the Sikeshu depression.
Elastic time-reverse modeling imaging conditions
Authors: Artman Brad
Published: May 2016

Since the Earth is elastic, it is worth the computational burden to process multicomponent data for elastic phenomena with fully coupled time-domain wave-equation propagators. At every time sample in the back-propagated model domain, the complete wave field is decomposed exactly into compressional and shear wave components by simple spatial derivatives. Then, physically significant images are extracted from extrapolated hyper-cubes by applying appropriate imaging conditions. To locate subsurface sources (or diffractors) with the time-reverse modeling algorithm, the imaging condition required is the correlation of P and S energy since only at the source location are the two events collocated. The impulse response of the algorithm is anti-symmetric in physical space and can be enhanced through post-processing with a spatial derivative or integral.

Source Focusing

The time-reverse modeling (TRM) algorithm was developed for locating sources within a model domain (Fink, 1999; Gajewski and Tessmer, 2005). The method is suited for locating earthquakes, microseismic events, or tremor sources. The difference between TRM and reverse-time migration (RTM) (Levin, 1984) is the lack of a known source wave field for TRM. Otherwise, data are treated in the same manner: reversed in time and used as source functions at the acquisition locations.

The difference between a specular reflection and a stimulated heterogeneity, or diffractor, is that data contain only a direct arrival ray path: The "from-path". This contrasts to reflection seismic whose time delays are the sum of the "to-path" and the "from-path." Without some knowledge of the to-path, imaging algorithms based on delays between a reference event and a scattering event, including RTM and interferometry, are incapable of finding sources within a domain. In contrast, the TRM algorithm exploits the ability to collapse travel-time surfaces (hyperbolic cones) using wave-equation propagators.
Laboratory Studies At Reservoir Conditions On The Impact Of Acid Gas And CO2 Displacements On A Carbonate Matrix
Authors: Obeida Tawfiq A. , Kalam Mohammed Zubair , Al-Sahn Hani , Gibson Adrian P. , Masalmeh Shehadeh K. , Zhang Hongmei
Published: May 2016

Laboratory studies have been performed to evaluate the impact of acid gas (80% H2S, 20% CO2) and CO2 injection on the carbonate matrix properties at reservoir conditions. Injectivity abnormalities have been reported in the literature in several WAG projects involving CO2 and loss of injectivity has been crucial factor in many of these projects. However, literature data shows that some reservoirs loose injectivity and others increase injectivity after the first CO2 slug is injected. Change in rock properties due to fluid/rock interaction can account for some of the injectivity loss.

In this paper we will report on recent laboratory study that was conducted using limestone and dolomite reservoir core samples from a carbonate reservoir in Abu Dhabi. The laboratory program used core plugs, or plug composites, that had been aged with reservoir oil at a representative initial water saturation prior to the gas displacement. The displacements were performed with three fluids:Vapor phase CO2Acid gas (80% H2S, 20% CO2)Brine saturated with CO2

The vapor phase CO2 and acid gas displacements were considered to be typical of those found near a gas injector, whereas the brine saturated with CO2 displacement was more representative of the reservoir away from the well bore or found during a WAG process. The displacements were conducted at a series of increasing rates. After 75 pore volumes the plug was left to soak for 48 hours in the displacing fluid. Two further displacements were then performed. Following the displacement tests, an assessment of damage to the core plug was made by measuring the porosity, permeability, SEM, XRD, MICP and taking thin sections of the core plug. This paper also presents laboratory work to study CO2 solubility in different brine salinities up to 250 K ppm at different reservoir temperatures up to 149 C and pressures up to 400 bar. A CO2 solubility model is proposed to calculate solubilities at representative salinity and previlent pressures and temperatures.

The preliminary results show that in most of the experiments no significant change in permeability was observed. However, in some experiments both enhancement and decrease in permeability was reported. The results of this ongoing study will strongly impact the planning of EOR development options. Injection of CO2 or acid gas will be significantly hampered if the gas injection results in matrix plugging or core damage, and needs to be appropriately evaluated for the reservoir under consideration.
Multi-Component Seismic Applications for Maximizing Efficiency and Production
Authors: Maili Eduard , Negulescu Carmen
Published: May 2016

Carbonate reservoirs are often very heterogeneous and their properties are frequently difficult to understand. The presence of faults and intense natural fractures further increases the complexity that becomes very challenging for reservoir management and field development. This is the case of the Shuaiba reservoir in Idd El Shargi North Dome (ISND) Field in offshore Qatar. The field was discovered in 1960 and was first produced in 1964. The oil is produced from multiple reservoirs, primarily carbonate, on a salt induced faulted anticline. After 1995, when Occidental Petroleum assumed the operatorship role under a Production Sharing Agreement with the State of Qatar, an extensive horizontal well drilling and waterflood campaign resulted in a substantial production increase from the primary Arab and Shuaiba reservoirs. This paper will focus on the Shuaiba development results. New technologies have been applied to effectively manage the Shuaiba waterflood and continuously increase the oil recovery factor in this complex reservoir.

The practical aspects of multi-component seismic technology described in this paper can be applied in any complex fractured reservoir for improving efficiency and increasing recovery.

During 2003–2005, Qatar Petroleum and Oxy acquired and processed a large 4C3D seismic survey over Idd El Shargi field (Fig.1). This technology uses multi-component phones and cross-spread acquisition geometry to record both compressional and shear (converted) waves. The survey ensured full azimuth coverage to offsets up to 3000 m, equivalent to an offset/depth ratio of two for the main target zone, achieving a nominal fold of 240 in the natural bin size, or a trace density of more than 2.7 million traces per square kilometer. The data were processed through a flow that carefully preserved the azimuthal anisotropy (Angerer et al, 2006).
Preventing and controlling endemic diseases in a pipeline construction in Amazon region
Authors: Chimelli Mauricio Abi Ramia , Alves Lima Gilson Brito
Published: May 2016

Preventing and Controlling Endemic Diseases in Amazon Region were identified as the most important action of the work environment. This project was implemented during the URUCU-COARI-MANAUS pipeline construction as a model project to be improved in Health, Safety and Environmental (HSE) practices. After discussions with management and other stakeholders, several teams of prevention agents were trained for the project's development. Actions were taken to import HSE knowledge and training to all on site personnel indicated by contractors. The main focus of the actions was on worker's immunization and workplaces fumigation necessary for the project improvement. The validation of the training and implementation of actions was closely monitored by the Health, Safety and Environmental (HSE) Petrobras teams and by the stakeholders. There were 9.000 workers in the middle of Amazon forest during the construction and no endemic diseases infected them. There were 499 confirmed cases of Malaria in workers; however, all of these workers were contaminated before workplaces entrances, ratifying the project's control success. The implementation of this project resulted in one hundred percent (100%) of workers immunized for Yellow Fever, Tetanus, and Hepatitis A and B. During construction, the incidence of Malaria in surrounding communities decreased around thirty percent (30%). Project benefits' include lower accidents rates, because the Brazilian legislation considers as accident, the appearance of endemic diseases in workers, and several new water treatment in surrounding communities in order to prevent water transmissible diseases which are very common in Amazon Region. This project resulted in trained of experts among local, which are now capable of preventing and controlling endemic diseases.
Pearl GTL Village - Setting New Standards
Authors: Fabricius Niels , Hodder Lee , Ring Ben
Published: May 2016

The Pearl GTL Project is a fully integrated upstream/downstream project producing 140,000 bbls per day of GTL products and 120,000 boe per day ethane, LPG and condensate. It is located in the Ras Laffan Industrial City (RLIC), some 80 km north of Doha in Qatar.

Much has been written and presented on the large dimensions and complexity of this world scale project, amongst others highlighting the fact that over 48,000 workers are involved during the peak of its construction activities. This paper will describe the infrastructure facilities and support functions that have been established to accommodate a large number of workers in RLIC.

Recognising that many workers will be involved in the project for several years, there has been a conscious move away from the idea of simply a 'camp', and the facility's name, 'Pearl GTL Village', reflects the aim to be more of a community. So, workers - who have come to Qatar from more than 60 countries to build the GTL plant - do not just sleep there: they live in the Pearl GTL Village, which has been developed into a fully-fledged community that makes the workers feel at home. The differentiators include:• The 'Al Muntazah' recreational area, in the heart of the Pearl GTL Village, includes sports fields (cricket, football, basketball, softball and tennis), an outdoor movie theatre, food stalls, shops, Internet cafes, places of worship and shaded seating areas.• Across the Village, there is a workforce of over 1,800 to keep everything up and running, including almost 500 cleaners and over 1,000 kitchen staff. In addition, there are medical facilities, and there is a welfare team including qualified counsellors.• An overall management team, led by a Village Mayor in place to ensure that consistent operational and welfare standards are applied across Pearl GTL Village.

The entire village is supported by infrastructure facilities that include a sewage system, combined potable water and fire water system, power distribution throughout the camp supplied initially by 84 diesel generators and later by a 33kv direct feed from a new Kahramaa substation, a telecommunications network for both voice and data for the entire camp, common recreational facilities, a waste water treatment plant equivalent to that needed for a small town to process sewage from the camp, roads and fencing.
Produced Water Management - Global Best Practices and Total Cost of Ownership
Authors: Walsh John Michael , Khatib Zara , Nabulsi Randa Zaki
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Produced water volumes from E&P operations are on the rise world wide. This is generally due to premature water production with oil in fractured reservoirs or due to mature fields undergoing a strong water drive or due to water breakthrough from waterflooding. The management of produced water is an important part of cost effective field development over the entire life cycle. However, all too often the economic impact of water production is not fully realized until late in the field life when the cost of mitigating such high water volumes has become prohibitive. What is needed is a better understanding, early in the field development stage, of the likely total cost of handling produced water over the life of a field. Using a total cost of ownership framework, produced water handling costs will be discussed for different water management options including well completions options, water shut-off, produced water treating, and various ultimate destination options such as overboard discharge, waterflood injection, subsurface disposal, constructed wetlands (reed beds), evaporation ponds, and beneficial use options. Examples from offshore locations such as Brazil, US Gulf of Mexico, the North Sea, and on-shore locations such as Oman, and Saudi Arabia, will be discussed. Experiences from these several different regions represent a wide range of water management strategies, water cut, produced water handling practices, and environmental challenges. Comparison and contrast between the practices of different regions will be used to identify best practices. Analysis of real costs will be used to determine if the same concept can be applied regionally and water management practices can be sustainable. Ultimately, economic analysis of currently producing fields is used to predict the total cost of ownership of produced water, on a risked-basis over the life of a new project.
Underbalanced Drilling in Shales- Perspective of Mechanical Borehole Instability
Authors: Islam Md. Aminul , Skalle Pal , Evgenity Tantserev
Published: May 2016

Drilling with a bottomhole pressure less than the formation pore pressure (Underbalanced Drilling, UBD) usually increase the risk of borehole instability due to yielding or failure of the rock adjacent to the borehole. But evaluation criterion of this failure mechanism is complex and very often diagnosis did not fit with field operational practices. It is believed that, shear and radial tensile failures with negligible chemical instability are the common mechanisms to cause mechanical instability in UBD in shales. In a mechanical borehole instability perspective, UBD causes lots of potential challenges and formation uncertainities due to facts like:- Insufficient case data related to borehole instability;- Complex physics of borehole instability mechanisms ;- Requirement to conduct excessive experimental work which is costly and time consuming;- Scarcity of real shales specimen and reluctant for coring of shales;- Reliability of fitting material constitutive model to analyse shales;- Dependable model to predict wellbore collapse pressure;- Uncertainty to predict pore pressure and permeability of shale formation;- Variable pressure regimes (i.e., shale heterogeneity);

A detailed workflow in connection within physical, experimental, analytical and numerical investigation is required to understand and to diagnose borehole stability. Numerous studies have been carried out so far on borehole stability design, but UBD and shale instability is quite new research areas where more insight is needed. This paper discuss and presents mechanical borehole instability both analytically and numerically to quantify borehole collapse risk for inclined wells. In addition produce comparable results and therefore some physical models are also presented for in depth study. Results show that the analytical and numerical models competent to predict borehole collapse risk in terms of minimum mud weight window. Since several real- life situations were evaluated, the potential applicability of the models is apparent; the results could be used as cross checks for particular situations in the field.

The generality of this study provided an overview along with standard workflow into borehole collapse assessment which may helps to obtain proper diagnosis of material failure state with respect to reduction of instability in drilling. Findings of this study can be useful for further research within the same area.
Heavy Oil: Development Challenges and Implementations of Technologies and Processes in an Investment and Carbon Constrained World
Authors: Khatib Zara , Brock Valerian Albert , Van Dorp Johan Jacobus
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Heavy oil offers a large potential resource base for meeting the world's long-term energy needs, however these are more difficult barrels to recover and face a number of challenges. In the near term, the global economic crisis has led to a dramatic reduction in the hydrocarbon prices, which led to the slow down and / or reconsideration of the investment conditions and resulting in postponing few of the major complex and costly projects. There is also growing emphasis on reducing greenhouse gas emissions. On the other hand, it is it clear that long-term energy demand will continue to surge, due to a growing global population of over 3 billion and the rising standards of living emerging economies such as China and India. While there is still plenty of oil left in the ground, easy oil supplies are declining rapidly forcing the global petroleum industry to turn to unconventional oil deposits that are costlier to recover. The current estimate of extra-heavy oil and oil sands (IEA) is more than four trillion barrels-in-place with very large deposits in Canada, Venezuela, Russia, and the Caspian. Several GCC countries such as Kuwait and Saudi Arabia are exploring how to assess and unlock the huge and largely unexploited reservoirs of heavy crude. How much of the resource can be recovered will be dependent on emerging technology and processes. This paper will- Highlight the technical challenges in developing heavy and extra-heavy oil,- Focus on a range of technologies and processes that have been used to boost production in the past 40–50 years bringing examples from the Aera, California operational excellence in producing heavy and extra heavy oil, and- Outline the recent technology developments that are currently implemented and/or will be utilized in the next decades, such as In-situ Upgrading and SAGD projects in Canada and the TAGOGD in fractured carbonates in Oman.

These field examples from Middle East and North and South America will be presented to demonstrate best practices and to provide insights on industry's future ability through technology to lower costs and increase the size of the resource base while increasing energy efficiency in operations, utilizing alternative solar energy for steam generation, and minimizing the overall impact on the environment.
Customized artificial formation for LWD platform tool development and manufacturing
Authors: Labous Laurent
Published: May 2016

A cost-effective and innovative test setup serves to qualify the new, highly integrated formation evaluation tools. This setup shall help reduce the risks associated with the tool development and later shall integrate into the manufacturing test chain.

The setup is a 4.5 meter high stack of quarried rocks immersed in fresh water. From bottom to top the stack includes three equally thick layers: a porous sandstone, a low-porosity limestone and an azimuthal combination of both. A high quality 10.5 inch diameter hole traverses the three layers. The measurements are recorded in various conditions to characterize the tool's azimuthal and vertical response.

We discuss the requirements for this installation and provide technical details for the construction of the stack, in particular the procurement and the saturation procedure. Various trade-offs are reconciled between cost, time to delivery, operational and physical specifications. The geometrical arrangement of the rocks and their lithology can be customized for a particular tool. The setup itself can be dismantled, modified and even duplicated.

This testing facility adds value to the product development cycle and commercial qualification of the tool. This project illustrates the more general need for new, innovative test equipment and procedures to efficiently qualify and characterize new integrated technology. Key features of the setup which make its strength and value are highlighted as they should guide the design of any similar test equipment. The principle and techniques can be applied to the development of other well-logging tools. This paper focuses on nuclear measurements; however, the method can be extended to other measurements (e.g. electrical, acoustic,…).

Introduction

A new platform integrating LWD triple combos is developed. It combines in a single collar, measurements from previous-generation tools along with a suite of more advanced measurements made possible thanks to pulsed neutron technology1,2. Figure 1 shows a drawing of the tool with a list of all the measurements.
Application of Advanced Dynamics Modeling Significantly Improves the Stability of Rotary Steerable Drilling with Roller Reamers, Mexico
Authors: Perez Tellez Carlos , Bedino Henry , Casanova Ocdomar , Castelazo Paulina Cuellar , Wu Xianping , Mayol Julio , Paez Luis Carlos , Verano Fernando , Columba Julio
Published: May 2016

In high profile applications, an advanced drillstring dynamics modeling system has been used to mitigate downhole vibrations and improve penetration rates (ROP). The capability of virtually drilling a well with computer software allows the engineer to identify the root causes of damaging vibrations and ROP limiters before drilling commences. Consequently, the conventional trial-and-error methodology can be replaced by a cost-effective optimization process. This technology provides an efficient platform to optimize the total drilling system including bit selection, bottom-hole-assembly (BHA) design, operating parameters and the placement of individual BHA components. The utilization of this software has delivered significant economic benefits associated with increased total footage, higher ROP and fewer downhole tool failures. Offset well data are used to calibrate the simulation for each application including:- Physical characteristics of the drillstring, BHA and drill bit- Operating parameters, weight-on-bit (WOB) and revolutions per minute (RPM)- Rock properties; in some cases, core samples from an offset well are tested- Well trajectory and hole diameter from directional surveys and caliper logs

The authors believe this technology has the potential to be a central optimization platform for a broad range of worldwide drilling applications.

Introduction

Historically, drill bits were the primary focus of the optimization process because of their impact on vibration, directional control and ROP. However, with the increasing use of sophisticated downhole technology including rotary steerable systems (RSS), roller/under-reamers, MWD/LWD and other specific tools, the modeling system has been increasingly applied to address stability issues caused by downhole tool dynamics.

Application Background

While drilling the 12-1/4" hole section with a push-the-bit RSS/PDC bit BHA on Tizon 222, Tabasco, Mexico (Figure 1 and Figure 2) the operator encountered low ROP and severe stick-slip associated with excessive torque. In order to reduce torque and improve ROP on the next well (Tizon 231), a service company recommended using a roller reamer in the BHA to efficiently drill from 3360m to 5370m while holding inclination angle. Based on previous experience, the placement of the roller reamer is critical in achieving overall BHA stability and achieving the desired ROP. The operator requested an optimization study using a dynamic modeling system to ensure a good balance between BHA stability and ROP. The capability of simultaneously quantifying the magnitude of vibration shocks and rock removal rate enabled the engineering team to address the challenging formation with confidence.
Gas as a Raw Material for Future Petrochemical Industry
Authors: Sadeqzaddeh Majid , Keyvanloo Kamyar
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Currently the petroleum-derived cuts are the dominant feeds for the petrochemical industry. However, a new situation is being emerged, and the natural gas is coming into play. The rapid growth in the petrochemical/ polymer sector, sensible decline in the world oil reserves, and increased crude oil price, are the reasons behind this evolution. This perspective is much more evident in the Middle East region, where the abundant gas resources can readily be found. The current paper is developed in two parts. In the first part, the current state of gas in the petrochemical industry is examined. The use of natural gas feed is studied considering different processes and products, geographical situation, added value, and the existing technologies. The second part peruses the changes that occur in this pattern until 2030. Developing technologies, foreseen projects, geopolitical effects, and the final price of different products is completely analyzed and a comprehensive pattern is introduced. Although different products are under study including Hydrogen, fertilizers (through ammonia), methanol, different polymers, etc.; special attention is given to the polyolefins (i.e. polyethylene, and polypropylene) due to their importance and high volume production. These two products are fully analyzed and the use of ethane crackers is studied in a comprehensive manner. It has been found that the natural gas can be regarded as a promising feed for the future energy industry due to several reasons, and among all the locations, the Middle East region is considered as the best potential point for such a development. Cheap gas prices, high state of integration between gas refineries, petrochemical complexes, and polymer plants, as well as existing infrastructure for new developments, high ethane content (compared to natural gas derived from other world reserves), are some of the reasons which make the Middle East the core part of this new vision. This paper is prepared in order to be served as a guideline for the industrial decision-makers, having in mind that the reliable academic and industrial resources used here make this task much easier.
Advances in Subsea Wet Gas Compression Technologies
Authors: Hjelmeland Mads , Olsen Arne B. , Marjohan Rudi
Published: May 2016

Subsea pumping- and metering represent technologies which may contribute to simplifying and enabling developments of marginal, and remotely located oil & gas fields. The Asia Pacific region has already seen several subsea implementations of the multiphase technologies over the last years which include both subsea boosting- and metering. The multiphase technologies are particularly suitable for offshore- and subsea operations, and offer the operators a cost- effective solution.

The multiphase technology area has gained experience through successful operation since the mid 90s. The fact that natural gas has increased its value in many parts of the world, has driven the request for the next technology step - wet gas compression. However, there are two different system approaches to this challenge;

- True Wet Gas Compression - subsea rotating machinery working directly on the wellstream without or limited preprocessing,

or

- Subsea Gas Compression - marinized dry gas compressors with upstream well-stream processing and associated control systems

This paper describes the development and full- scale test of a Multiphase Compressor, which is working directly on the well stream without pre- processing. A description of how this technology can simplify complex offshore field developments will be given, as well as an overview of the operating characteristics and main features of the compressor.
First Application of Gasified Fluid Drilling in Pakistan
Authors: Asrar Muhammad , Majeed Shahid
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

This paper presents the planning phase, operational results and future recommendations of first well drilled with Gasified Fluid Drilling technique in Pakistan.

The project's goal was to minimize non productive time associated with drilling operations and reach the target depth safely. Total loss circulation events were observed while drilling highly depleted and fractured Limestone Reservoir with conventional drilling techniques in offset wells. This led to adopt technology of Gasified Fluid Drilling for very first time in Pakistan.

A multidisciplinary team planned and executed operation. Objectives were met with no downhole fire, minimal lost circulation and no formation influx. Results from this well showed significant increase in penetration rates and hole cleaning in comparison to offset wells.

This application opened new ventures and recommendations for further mature fields development in Pakistan.