bluuebunny/crossref_metadata_2025_split huggingface dataset:
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.

Abstract
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

ABSTRACT
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.

Abstract
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

Abstract
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

Abstract
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.

Abstract
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

Abstract
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.

Abstract
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.
Monobore Solid Expandable Liners - Redesigning wells for a more Economical and Operational Benefit
Authors: Siddiqui Asim A. , York Patrick 
Published: May 2016

Abstract
Solid expandables liners have historically been viewed as contingency liners when operators encounter trouble zones, whether due to setting a conventional casing string high or covering unstable or loss of circulation zones or to improve drilling margins. In that event, the method of operation changes from drilling the well to saving it and still reaching total depth (TD) with the designed production string. At this point the expandable liner typically is run in a high-risk situation when the operator is attempting to save the well. It is more beneficial to design expandable system(s) in a hole section further up the wellbore where the liner would be run in a much lower risk environment.
Designing a monobore solid expandable liner into the casing program enables the operator to significantly reduce risks by incorporating another liner string in the well design without losing hole size. Additional benefits can be achieved as the liner requires less pressure to expand rather than running a smaller liner where expansion pressures are higher, reducing associated operational risks.
Alternatively, the monobore design can also reduce the number of casing strings run to TD by drilling smaller holes and using less mud and cement while maintaining the same size completion. This type of well construction methodology can lower the overall cost of the well and enable a smaller rig to drill a deeper hole. This methodology enables operators to use conventional high-strength casing to address high-pressure trouble zones further down hole where the expandable liner capabilities may be exceeded.
This paper will discuss operators' original basis of designs (BoD) of several application types, the redesigns to incorporate expandable monobore well systems, and the economical benefits they provide.

Introduction
Although the use of conventional solid expandable liners can result in significant conservation of hole size and "slowing" the telescoping effect of the wellbore (York 2008) as illustrated in Figure 1, some inside diameter (ID) reduction always occurs. The resulting non-API ID of the expanded liner can drive up well construction cost due to the relative scarcity of subsequent drilling equipment such as drill bits, bottomhole drilling assemblies (BHAs), and even retrievable test-treat-squeeze (RTTS) tools and packers. The use of expandable monobore liners can eliminate the need for these "odd" size equipment requirements.
Since introducing solid expandable liners in 1999 (Filippov 1999), end users have looked to expandables to not only extend casing shoes with drilling liners, but to do so without sacrificing any hole size in the process. This methodology is being implemented in several arenas and in several available sizes (York 2004, Jabs 2004, Filippov 2005). The monobore term, in reference to expandable technology, is defined as a solid expandable liner that when installed does not result in the loss of diameter of the wellbore (Figure 2).
Exploiting the Synergies by Combining Multilateral Well Intervention Techniques with Real Time Downhole Measurements Lessons Learned from Trilateral Horizontal Well Stimulation in the Partitioned Zone
Authors: Al-Rubaiyea Jamal , Attiea Adel , Al-Hadyani Fahad S. , Nugraha Ikhsan , Boonjai Pimteera , Erkol Zafer 
Published: May 2016

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

Abstract
Multilateral wells pose a unique challenge to operators when planning for any intervention. Correctly accessing and uniformly acidizing all laterals continues to be challenging. While lack of reliable downhole data and knowledge about naturally fractured zones or poor correlation between porosity and permeability in carbonates limit the effectiveness of a stimulation treatment; sometimes the inability to access all laterals even prevents the lateral from being acidized at all. These limitations in acidizing, therefore, provide lower than expected gains.
Selective lateral access by using coiled tubing multilateral entry tools (CTMET) have provided a first step to selectively place fluids in each lateral. However, even selective lateral access cannot provide positive confirmation that treatment fluids are confined to the intended lateral. New downhole measurements with fiber optic assisted coiled tubing (FOACT) seek to mitigate some of the uncertainty that prevails in such well interventions.
This paper describes an innovative approach adopted for the stimulation of a tri-lateral open-hole carbonate oil producer in Kuwait. The distributed temperature survey (DTS) and real time downhole data obtained from FOACT was used in conjunction with the CTMET to map and access all laterals. The DTS profiles were used to track real-time temperature changes between fluid stages of a stimulation treatment. Identifying and prioritizing which lateral to stimulate first, lateral injection distribution, formation fluid invasion, diverter efficiency and changes to the injectivity profile were interpreted in real time to improve the fluid placement.
The paper describes the effect of combining MLRT (multi lateral reentry techniques) with the fiber optics technology simultaneously and the lessons learned from this innovation. This synergistic approach not only improved operational efficiency, well-site safety but also resulted in reviving production from a previously dead well in a cost effective manner for the operator. As a result, the entire approach towards multi-lateral well stimulation in Kuwait was revolutionized with renewed confidence towards achieving better results in future interventions.