bluuebunny/crossref_metadata_2025_split huggingface dataset:
Synergistic Chemistry Tailors Invert Emulsion Fluids (IEF) with Consistent Rheology to Minimize Equivalent Circulating Density (ECD) Fluctuations
Authors: Kulkarni Dhanashree , Maghrabi Shadaab , Wagle Vikrant 
Published: December 2014

Abstract
Consistent rheology is crucial for the successful construction of a deepwater oil/gas well. Oil wells with water depths greater than 5,000 ft are an industry norm, with temperatures at the seabed close to 40°F. There is a continuous need to drill with products that are environmentally-acceptable and yet technically capable. At cold water temperatures, invert emulsion fluids (IEFs) typically exhibit a significant increase in rheology, becoming noticeable in the riser after static periods. To break circulation after static periods or while circulating, the high rheology of the IEF necessitates high pump pressures to initiate or maintain circulation. High pump pressures mean high equivalent circulating densities (ECDs) at the bottom of the well, increasing the probability of losses. Fluid losses in deepwater wells can be costly, considering the difficult logistics.
Traditionally, thinners are added to the IEF to pre-empt an increase in rheology in cold waters and to help minimize the ECD. This entails precise control over the rheology of the IEF along the depth of the well, especially in the hotter regions. Failing this can result in the poor suspension of barite or drilling cuttings. A desirable IEF has a consistent rheology from the platform to the riser and to the bottom of the well.
Wagle et al. (2012) describe an organic rheology modifier (ORM) that delivers a consistent rheology to the IEF in temperatures ranging from 120 to 400°F at 18,000 psi. Taking this a step further, an additive to the ORM (AORM) was developed that synergistically interacts with the ORM in the IEF. The IEFs formulated with the AORM and ORM in three base oils common to deepwater operations demonstrated the following:
Consistent rheology from 40 to 150 to 350°F at 15,000 psi and higher. Improved suspension to barite particles.
Furthermore, both the AORM and the ORM passed the stringent toxicity and biodegradation required for use in the North Sea.
Engineering, Procurement, and Construction Challenges of Oil and Gas Artificial Islands in the Arabian Gulf, Part 2: Settlement Prediction of Shallow Foundations
Authors: El-Gharbawy Sherif , Fioravante Vincenzo , Giretti Daniela 
Published: December 2014

Abstract
The Abu Dhabi oil and gas industry, represented by ADNOC companies, is currently developing an array of artificial islands across its Exclusive Economic Zone in the Arabian Gulf for applications ranging from new field development and upgrade or expansion of storage and offloading facilities, to the creation of accommodation villages for offshore personnel. With favorable water depths and environmental conditions, land reclamation is often a more economical option than the construction of fixed steel jacket platforms. ADMA-OPCO is currently engaged in applying land reclamation technology to projects such as the Satah Al-Raaz Boot (SARB) field development and the Das Island Development (DID). SARB is a 105-mbd development comprising 86 wells on two artificial islands. While cost and schedule optimization will be realized with the selection of the land reclamation and artificial island option for these mega projects, geotechnical and marine engineers are facing project-specific challenges such as the development of performance criteria for the fill material used in the construction of the islands and assessment of the ground improvement works. The fill material consists of natural soil (biogenic carbonate sand) dredged from the local environment with varying fines content and mechanical characteristics. Once deposited, the sand is compacted to achieve target performance. The major geotechnical issues related to the performance of fill material are its deformability under the working loads of the drilling facilities, which are generally founded on shallow footings, and its resistance and deformability during seismic loading. A method for the computation of short term settlements of shallow foundations under static loadings is proposed. The method, which has been implemented on a worksheet to provide a simple computational tool, is based on the use of the equivalent linear elasticity and is verified by means of model plate load testing of the fill material conducted in the centrifuge laboratory and zone load tests conducted on the SARB islands.
Effect of CO2 Sequestration Period on the Mechanical Properties of Carbonate Aquifers
Authors: AL-Ameri Wahbi Abdulqader , Abdulraheem Abdulazeez , Mahmoud Mohamed , Abdullatif Osman , Adebayo Abdulrauf Rasheed 
Published: December 2014

Abstract
Geological sequestration of carbon dioxide (CO2) in underground formations is the most promising way to decrease the greenhouse emissions into atmosphere. The understanding of long term effects of CO2 storage in carbonate aquifers is challenged by many uncertainties including geochemical effects of CO2 on carbonates and the coupled chemical–mechanical effects. The carbon dioxide dissolves in water forming bicarbonate which will dissociate to carbonic acid. This acid dissolves calcites in carbonate rocks. As a result, the mechanical properties of the aquifer changes through this interaction. It is therefore necessary to study the effect of carbon dioxide sequestration on the integrity of a given formation to get safe and effective long-term storage of CO2 sequestration in deep saline aquifers. To the best of our knowledge, previous works on CO2 sequestration have focused on the impact of CO2 injection on the petrophysical and mechanical properties of formation rocks but the injection occurred in a short period, which was not enough for carbon dioxide to react with formation brine and thus the chemical reaction that will impact the properties of the rocks.
The main objective of this paper is to investigate the effect of CO2 storage on the mechanical properties of carbonate aquifer rocks that were exposed to soaking with CO2. Furthermore, the effect of the duration of CO2-brine contact time or solubility time on these properties was investigated. CO2 was stored in the cores at 2000 psi and 100°C for different time periods ranging from two weeks to three months. The cores were then analyzed for the mechanical properties using acoustics, unconfined compression, and indirect tensile strength testing machines.
Results showed that storing CO2 for longer times changed the rock mechanical properties significantly. Samples in which CO2 was stored for longer times exhibited greater change in mechanical properties compared to those in which CO2 was stored for shorter time. The geochemical interaction between CO2, brine, and rock is time dependent making changes in rock mechanical properties also time dependent.
First Successful Hydraulic Fracturing in the Offshore Abu Dhabi: Part1—Flexible Design to Unlock a Tight Gas with Uncertainties—
Authors: Kuroda Shintaro , Kaneko Masayuki , Al Ameri Fahed , Al Zarouni Asim , Al Zaabi Mohamed R. , Al Awadi Farhaad Khaled , Sabri Abdul Moez 
Published: December 2014

Abstract
The hydraulic fracturing technology is widely applied in tight reservoirs, including shale reservoirs, as one of the established reservoir stimulation methodologies to enhance the productivity. Even though the hydraulic fracturing is currently a common technique, there are remaining challenges in offshore fields with the high degree of geological and geomechanical uncertainties. In offshore hydraulic fracturing operations, key issues are the limited deck space for the required equipment on-board and economical aspects of the surface equipment including stimulation vessels due to the limited number of dedicated offshore stimulation vessels in the world. In addition, the limited reservoir information brings uncertainties in the hydraulic fracture design and causes difficulties in finalizing the operation plans from the timing and logistics point of view.
This paper contains the first part of the two successive parts of a case study will be shown on successful optimization and productivity enhancement of actual offshore hydraulic fracturing for a deep tight gas reservoir with considerably limited formation data and under a high-pressure and high-temperature (HP/HT) environment. This successful operation was recognized as a landmark in this region, in terms of the first hydraulic fracturing operation in the offshore Abu Dhabi.
In this paper (part 1), we describe how the flexible hydraulic fracture design led to an efficient productivity enhancement. The hydraulic fracture design was optimized by the integrated data acquisition strategy and the successive flexible adjustment from the design stage at office to the actual main treatment at wellsite. The relevant fracture design components like proppant usage and size can be optimized, based on sensitivity studies assuming not only all possible geological and geomechanical circumstances but also the actual pre-frac well test and data-frac results. In part 2, the key factors will be highlighted on this successful hydraulic fracturing result against the difficulties from operational point of view (Al Ameri et al. 2014).
The work flow and successful strategy in our hydraulic fracturing design and execution can be applied to other offshore tight-sand gas reservoirs including those under HP/HT condition. The optimized design of hydraulic fracturing provides an effective operation and enables more economical field development for the tight reservoirs.
Review of Downhole Wireless Communication Techniques
Authors: Arsalan Muhammad , Ahmad Talha J. , Noui-Mehidi Mohamed N. 
Published: December 2014

Abstract
Real-time permanent monitoring and control is essential to maximize production from oil and gas wells. An interdisciplinary approach is needed for any cost-effective solution that can perform and be sustained in the harsh downhole environment. For open hole horizontal wells, providing power and data through an umbilical is very challenging. Wireless communication is the essential component of any downhole monitoring and control solution in this situation. A wireless solution can also significantly reduce the complexity and cost associated with the wired solutions. In this paper various wireless communication techniques are classified and an extensive review of state-of-the-art downhole applications is presented. Advantages and limitations of each technique are discussed and recommendations are made of possible solutions.
Performance Evaluation of High Temperature Fracturing Fluid
Authors: Prakash Chetan , Achalpurkar Manoj P. , Uppuluri Ramesh 
Published: December 2014

Abstract
Hydraulic fracturing has remained a fundamental technique for stimulation of oil and gas reservoirs for enhanced or economic recovery of hydrocarbons from tight formations. Transporting proppant downhole without any interruption and maximum recovery of fracturing fluids are two important criteria for successful hydraulic fracturing. To achieve such objectives, the fracturing fluid should demonstrate good viscosity and complete cleanup of gelling agents. As wells are exploited at greater depths in environments of higher temperature and pressure, fracturing fluid selection is key. Fracturing fluids prepared by crosslinking guar, guar derivatives, and other naturally occurring polymers with borate or metal crosslinkers often exhibit instability at very high temperatures. The key reason for instability of the fracturing fluid is because strength of the bonds between the polymer chain and crosslinker decreases sharply in addition to breakdown of the glycosidic bonds between monomer units of the polymer chain beyond 375°F. Additionally, metal crosslinked bonds are prone to shear degradation, creating doubt for a successful job in high temperature long reach wells.
To address these issues, a synthetic gelling-agent-based fracturing fluid that can work at temperatures greater than 400°F was developed. The gelling agent is a terpolymer, which can be crosslinked with a zirconium-based crosslinker. This paper discusses evaluation and performance of an extreme temperature fracturing fluid. This fracturing fluid system has sufficient proppant carrying viscosity and provides efficient cleanup using delayed oxidized breaker. Analysis of fluid stability and delayed oxidizing breaker usage is presented in addition to performance parameters, such as regained permeability and fluid loss. The study illustrates performance of the synthetic gelling-agent-based fracturing fluid at temperatures ranging from 380 to 420°F.
Delivering an Integrated Real Time Data Environment for Wells and Facilities Offshore Abu Dhabi
Authors: Kirkman Matthew , Said Ahmed A. , Said Saad , Jama Ali Ahmed , Didanloo Ali , Rivadeneira Marcello , Ettireddi Srinivas 
Published: December 2014

Abstract
ADMA-OPCO is currently pursuing the development of several undeveloped structures offshore Abu Dhabi. in addition to the two giant fields that have been on production for many years. At ADIPEC in 2010, ADMA outlined plans for real time well surveillance offshore. This paper describes the implementation of the first phase of these plans for three existing facilities, one of the new fields, and HQ. This paper presents some of the details of that implementation and the opportunities this creates for improved well management.
The paper covers: Hardware architecture and designSoftware philosophy and integration with existing capability at ADMA OPCOAreas of business value incremental to prior practicesWorkflows and visualization of key well and facility data
The challenges ADMA-OPCO faces offshore Abu Dhabi dealing with a high number of complex wells, are to ensure adequate drainage and optimum flux rates, to enhance overall recoveries, from reservoir intervals in both existing, and more complex new fields. Real time well and facility data, transformed with the addition of both modelling capability and workflows, can translate into automation of some key processes and the addition of value by guiding scarce engineer time into the areas requiring the most attention. With ADMA OPCO's activity growth, the well to engineer ratio is increasing. To enhance organizational efficiency, ADMA will be able to automate some previously manual tasks by implementation of automated workflows.
A phased approach to the introduction of real time data in an evolutionary, rather than revolutionary approach, preserving and augmenting the functionality of existing tools enables the implementation to follow the pace of introduction of additional control and surveillance capability into the Brownfield environment.
Determination of Leading and Lagging Indicators Utilizing the BowTie Methodology
Authors: Groot Arthur , Bekker Nicola 
Published: December 2014

Abstract
Process Hazard Assessments is a recognized tool for assessing process design and production operations around the world. However, the methodology utilized to assess hazards range from standard HAZID, HAZOP and SIL workshops to complex consequence models (computational fluid models). In most cases the workshops can be based on the number and experience of the professionals present and the level of detail and time allowed for the assessment. Process Hazard Assessments also tend to concentrate on risks typically encountered in the design phase and not the total life cycle of the asset.
The BowTie methodology offers a structured approach for assessing how well all initial threats are being controlled and how prepared an organization is to mitigate consequences should things go wrong. It highlights the direct link between (preventive and corrective) controls and management systems, which include operational management systems, Health, Safety and Environment management systems, and asset integrity management systems.
The BowTie methodology has to date not been widely utilized in the determination of leading and lagging Key Performance Indicators for the operational risk management systems, despite the availability of this methodology for several decades. To encourage using the methodology, an approach has been developed to determine the leading and lagging Key Performance Indicators utilizing BowTie's. This paper reviews this process and presents different experiences and lessons learned from applying the method within (petro)chemical and pipeline companies. Based on the results, recommendations are made and conclusions drawn about how the BowTie method can best be adapted for determining leading as well as lagging Key Performance Indicators.
H2S Measurement Using Wireless Technology
Authors: Phelan P. , Khouri A-R Shames , Wahed H. A. 
Published: December 2014

Abstract

Description
H2S represents a major hazard encountered in Oil and Gas production and the efficient and reliable detection of gas leaks is a critical safety aspect of this business. Wireless detection systems offer an opportunity to expand the measurement area however this must be achieved reliably.
Wireless technology has developed rapidly in the consumer market for mobile phone and computing applications. Development in the onshore Oil and Gas industry has been less rapid due primarily to the conservative nature of the industry and the need to ensure reliability, particularly for new technology applied to safety related functions.
This paper will review a specific application installed at GASCO Asab facilities of wireless technology in gas detection. The paper will detail the steps taken to assess the integrity of the wireless system and the considerations necessary to ensure the reliability and availability of the signal transmission.

Applications
Although this example applied specifically to H2S measurement in the environment it is an approach which is applicable to gas detection and measurement transmission for many applications. It therefore has wide application potential throughout Oil and Gas production.

Results and Conclusions
The technology of wireless communication can provide significant opportunities for performance enhancement in the Oil and Gas Industry. It is however imperative to systematically consider and document issues which may affect reliability and availability. Some of the key limitations in terms of reliability, coverage range, statutory compliance and maintainability are addressed in this paper.

Technical contributions
Integrated Project Delivery (IPD): A Paradigm Shift for Oil & Gas Giga Projects
Authors: Al Subaih A. S. 
Published: December 2014

Abstract
The nearly $100 billion in megaprojects planned for Mozambique, for example, is more than 400 percent of the country's total GDP, and the planned oil and gas investments in Papua New Guinea are 123 percent of GDP. Even in large, developed conomies, the size and scale of new oil and gas investments can represent a significant portion of the total economy. The combined value of Australia's new oil and gas projects represents nearly 20 percent of the country's $1.5 trillion GDP for 2012. The economic benefits to the country of getting the projects right are enormous(Deloitte, 2013).
Consumption and Production increased for Oil & natural Gas to record levels across the globe. As per the BP Statistical Review of World Energy issued in June 2014, of the total world energy consumption, a staggering 57% is from Oil & Natural Gas. The world oil Consumption has increased by 9.96% and the world oil Production has increased by 7.1% since 2004. Of the total 86.8 Million Barrels of Oil Produced per (BOPD) 32.6% is produced by Middle East and 4.2 % by UAE alone. Similarly of the total 326 Billion cubic feet per day (BCFD) natural gas produced worldwide 16.8% is produced from Middle East of which UAE produced 1.7% (BP, 2014).
In its World Energy Investment Outlook 2014, the International Energy Agency (IEA) estimates a cumulative investment of US$22.4t in the global oil and gas sector between 2014 and 2035, equivalent to an average annual spend of more than US$1t. Middle East is expected to invest around US$ 206b between the period 2014 and 2035. The IEA expects oil and gas spending to increase sharply, increasing by almost 50% from its average of US$678b per year over the 2000–2013 period (EY, 2014). Figure 1.1 shows the Regional cumulative Oil & Gas ivestments between 2014 and 2035.
3D Surface-Wave Estimation and Separation: Using a Closed-Loop Approach
Authors: Ishiyama Tomohide , Blacquiere Gerrit , Verschuur Eric 
Published: December 2014

Abstract
Surface-waves are often dominant in seismic data in a shallow water and land environment. Separating them out from the seismic data is of great importance for either removing them as noise for reservoir characterization, or extracting them as signal for near-surface characterization. However, their complex properties make the surface-wave separation significantly challenging in seismic processing. To address the challenges and adopt recent advances in seismic processing, we propose a methodology of surface-wave estimation and separation using a closed-loop approach. The methodology was successfully demonstrated on real 3D seismic data with mud-roll that is often dominant in a shallow water environment.
Applications of High-Resolution Imaging and High-Performance Parallel Computing in Unconventional Energy Recovery
Authors: Chen Cheng , Hu Dandan , Martysevich Vladimir 
Published: December 2014

Abstract
Two shale gas rock samples, from a Middle East shale gas play and the Eagle Ford shale play, respectively, were scanned using a nanometer-scale focused ion beam-scanning electron microscope (FIB-SEM). The geometrical properties were extracted and compared. The high-resolution image data were then processed and used as boundary conditions in the pore-scale GPU-accelerated lattice Boltzmann simulator (GALBS) for permeability simulation. The GALBS is based on the lattice Boltzmann (LB) method and optimized by graphics processing unit (GPU) parallel computing. Image processing showed that although the intrakerogen pores in the Eagle Ford sample had larger pore volumes compared to those in the Middle East sample, their morphologies were more laminar, which leads to higher friction to fluid flow and consequently gives rise to lower macroscopic permeability. GALBS simulations confirmed that the permeability was at the nanodarcy (nd) level in the Eagle Ford sample, while it was at the microdarcy (μd) level in the Middle East sample. Furthermore, anisotropy in the permeability tensor was observed in both shale samples. The computing speed of the GALBS is more than 1,000 times faster than the serial code and more than 10 times faster than the parallel code run on a standalone CPU, which suggests that many more samples can be analyzed given the same processing time. The combination of high-resolution imaging methods and high-performance parallel computing is a powerful tool for studying microscopic processes and upscaling. It provides for a more accurate estimation of the total stored gas and is helpful in the optimization of hydraulic fracturing treatments, which are aimed at connecting as many isolated intrakerogen pores as possible. The method presented in this study enables more accurate characterization of microscopic geometries and faster upscale transport properties, illustrating that unconventional energy recovery requires unconventional solutions.