bluuebunny/crossref_metadata_2025_split huggingface dataset:
Applicability Comparison of Nuclear Magnetic Resonance and Mercury Injection Capillary Pressure in Characterisation Pore Structure of Tight Oil Reservoirs
Authors: Zhao Huawei , Ning Zhengfu , Zhao Tianyi , Che Fei , Zhang Rui , Hou Tengfei 
Published: November 2015

Abstract
Applicability of experimental techniques is critical to accuracy of results. In this paper, a comparison was made between nuclear magnetic resonance and mercury injection porosimetry to clarify their applicability in pore structure characterization of tight oil reservoirs. Five tight sandstone core samples from the Upper Triassic Ordos Basin in China were collected for nuclear magnetic resonance, pressure-controlled porosimetry and rate controlled porosimetry. The T2 relaxation time distribution of nuclear magnetic resonance was compared to the pore size distribution calculated by a combination of pressure-controlled porosimetry and rate-controlled porosimetry.
The T2 distribution of sample Z211-1, N78-3 and T2-1 show three peaks, i.e. ~ 1 ms, ~100 ms and ~1000 ms. However, the T2 distribution of sample Z147-2 shows unimodal and that of sample Z117-3 shows bimodal, and the amplitudes are much smaller. For pressure-controlled porosimetry, the average final intrusion mercury saturation exceeds 80%, while the extrusion efficiency is low, indicating large pore-throat radius discrepancy. For rate-controlled porosimetry, the final intrusion mercury saturation averages 48.20%, and most of the mercury enters throats. The nuclear magnetic resonance T2 distribution and pore size distribution by a combination of pressure-controlled porosimetry and rate-controlled porosimetry show reasonable agreements. Rate-controlled porosimetry tends to overestimate the radius of pores, while some clay dominated pores are not water saturated. These might be the causes of differences between the nuclear magnetic resonance T2 distribution and the mercury injection porosimetry pore size distribution.
It is concluded that a combination of PCP and RCP can provide more accurate pore size distribution of tight sandstone, while nuclear magnetic resonance seems to be a fast and economical method.
Successful Utilization of Surface Jet Pumps at Gas-Oil Separation Plants
Authors: Al-Khalifa H. H. , Peeran S. , Koleshwar V. S. 
Published: November 2015

Abstract
Gas-oil separation plants consists of two or three separation stages to separate oil, water and associated gas. Oil flows to the stabilization plants and water to injection wells, while associated gas is sent to gas plants for further processing. At Plant A, the high-pressure (HP) gas has adequate pressure to freely flow to gas plants without compression; however, gas from intermediate pressure (IP) and low-pressure (LP) stages flows to a nearby stabilization facility to be compressed along with gases released from stabilization and sent to the same gas plant where HP gases were directed to.
Utilizing a surface jet pump (SJP) at Plant A was found to be an energy saving and economically attractive alternative as it enabled sending the IP gases directly to the gas plant without gas compression by using HP gas as a motive fluid.
This paper will discuss in detail the design basis of this application and few challenges faced during the test. Also, it will cover the wide range of operational envelop that the surface jet pump covered during the validation trial. The application was found to be successful and resulted in substantial savings in compression cost.
Advantages of using SJPs include using already available fluid energy within a process stream, no moving parts, zero maintenance, zero power or fuel gas usage, small footprint and varying layout configurations. SJPs are well suited to liquid ingestion and to changes in process conditions (without greatly affecting performance).
Unique Technology for 3D Integrity Monitoring of Subsea Pipes
Authors: Instanes Geir , Pedersen Audun , Simonetti Francesco 
Published: November 2015

Abstract
This paper discusses the latest developments in non-invasive corrosion/erosion monitoring with guided wave tomography for subsea and topside asset management. There are many technologies available for corrosion/erosion monitoring topside, but much fewer subsea. The subsea environment is difficult to access for instrument maintenance and verification of monitoring data, and many pre-installed systems have proven to be of little use. A technology for non-intrusive wall thickness monitoring based on ultrasonic guided waves has been available for permanent installation topside and subsea for some years. A subsea retrofit solution has also been delivered. The system utilizes ultrasonic guided Lamb waves to monitor wall thickness over extended areas; much larger than any spot measurement system with a comparable number of transducers. The ClampOn CEM® received a Spotlight on Technology award at the 2012 OTC. Monitoring data from this instrumentation platform are well suited as basis for tomographic processing to produce two-dimensional wall thickness maps of pipe sections. A technique has been established that holds promise of unprecedented capability for wall thickness monitoring, offering previously unavailable real-time imaging of eroding wall surfaces. Points of minimum wall thickness can be located, their depths can be measured, and their developments over time can be tracked.
Surface-Enhanced Raman Spectroscopy for Rapid and Cost-Effective Quantification of Amines in Sour Water
Authors: Benhabib Merwan , Tran Kim P. , Kleinman Samuel L. , Zherebnenko Natalya , Peterman Mark C. 
Published: November 2015

Abstract
Organic amines are corrosion control agents that increase pH and scavenge corrosive contaminants. Their presence in sour water can lead to the formation of heat-stable salts, resulting in potentially corrosive deposits. The measurement and monitoring of amines in sour water requires chromatographic techniques, with corresponding complexity, training, and expense. A rapid, field-deployable method to measure amines in refinery process waters would speed testing time, increase the temporal data resolution, and allow for immediate response and process adjustment. We present a new approach to amine measurement using Surface-Enhanced Raman Spectroscopy. By mixing a pH-adjusted sample with gold nanoparticles, a strong amine signal is obtained with a potential for sub-100-ppb detection. An optimized approach for ppm-level detection reports 27.8±3.9-ppm and 76.4±5.1-ppm for ~25-ppm and ~75-ppm samples, respectively, with more than one-hundred tests per sample over a three-month period. This method is at least as accurate, sensitive, and repeatable as ion chromatography, yet can be performed in the field in under five minutes.
Phase Behavior Evaluation of Sodium Stearate Emulsion System: Stability Tests in chemical EOR
Authors: Mavaddat Marzieh , Baharamian Alireza , Riahi Siavash , Fakhroueian Zahra 
Published: November 2015

Abstract
This work presents a laboratory phase behavior study of Sodium Stearate/brine/oil system. The quantitative and qualitative observation of the phase behavior of the microemulsion in a three phase brine/oil/emulsion system is reported (Winsor III). The experiments were designed to investigate the stability, interfacial tension (IFT), and viscosity of the emulsion phase in a wide range of temperature (25-60 °C), water-to-oil ratio (0.2 to 5), salinity (10 to 200,000 ppm), and surfactant concentration. The range of parameters was selected as what typically occur during a chemical enhanced oil recovery (EOR) process. The effect of pH variations was also studied by changing that of the system from 1 to 11, using different acid and alkalines. As the pH increases, the stability of the emulsion phase increases as well as the emulsion phase thickness. The viscosity of the emulsion phase was also monitored qualitatively for different temperatures. Moreover, using longer chain alkanes confirms the capability of the surfactant for chemical EOR process.
Achieving Sustainable Zero Flaring through Spiking Gas Compressor at ADCO Field
Authors: Reddy Dr. Vijaya , Samad Khalid Abdul , Bamadhaf Mohamed Omar , Arunachalam Subbiah 
Published: November 2015

Abstract
Gas flaring is a major source of Green House Gas (GHG) emissions and impacts public health due to release of harmful pollutants. Gas flaring from oil and gas industry contributes to 1.5 % of the global GHG emissions.
As part of efforts to improve the environmental performance, ADCO commissioned spiking gas compressors to recover the flared gas and avoid emissions to atmosphere. The associated gas from one of the mid-eastern field is spiked into main oil line until such time as the new Gas plant is fully stabilised. The compressor train consists of reciprocating three-stage compressor, knock-out drum, air-cooler to cool down the compressed gas, metering skid, and glycol Dehydration Package.
Adopting spiking compressor in middle-eastern field provided substantial economic and environmental benefits to the UAE in general and ADNOC / ADCO in particular. In addition to recovery of 98% flared gas, the project resulted in reduction of CO2 and improved the local air quality in the area. The project was registered under the Clean Development Mechanism (CDM) of the United Nations Framework Convention on Climate Change (UNFCCC) in 2013 to claim carbon credits. Implementation of this project demonstrates the commitment of ADNOC Group towards climate change mitigation and sustainability.
The paper details the technical features of the project, the environmental, economic, and social benefits associated with recovery of associated flared gas, and the CDM registration process adopted to claim actual carbon credits.
A Novel Particle-Type Polymer and IOR/EOR Property Evaluation
Authors: Wu Xingcai , Xiong Chunming , Xu Hanbing , Zhang Jian , Lu Changdong , Lu Xiangguo , Li Jinkui , Cao Huiqing , Zhang Na , Cui Guoyou , Chen JingJing , Ye Yinzhu , Jia Xu , Lv Jing , Yang Zhongjian 
Published: November 2015

Abstract
Traditional polymer flooding technology is difficult to be used in high temperature and high salinity reservoirs, due to the property limitation of HPAM. It is the key of chemical flooding EOR to develop a new type of polymer, which can tolerate high temperature and high salinity and has high sweeping capacity.
Through microemulsion / suspension polymerization technique, a new particle-type polymer is developed. The polymer size is in the range of 30 nm to 112 μm, and can be divided into three size sections: nanometer, micrometer, and submillimeter. The microscope is used to observe the appearance, and the apparent viscosity of the dispersion is also measured, with which the temperature and salinity resistance and water absorbing and expanding property of the new polymer can be evaluated. A 2.1 m long core model is made to test the in-depth migration of the polymer particle. The resistance factor and residual resistance facter evaluation method for traditional polymer is borrowed to test the retention property of the new polymer in cores. Parallel dual-pipe artificial and natual cores are used to simulate the IOR/EOR property of the new polymer for sand and carbonate reservoirs.
The lab tests show the new polymer can tolerate high temperature, 120 °C, and high salinity, 200000 mg/L. The polymer particle can swell by 3-10 times in water by hydration, but do not change much in oil. The apparent viscosity of the new polymer liquid is 1-3cp, so it can be easily injected into deep reservoir. It can increase water flowing resistance, but not increase that of oil. When being used, the new polymer is a type of discontinuous liquid distributed with soft polymer particles, which is different from the traditional polymer, HPAM, which is a type of continuous viscous fluid. The IOR/EOR mechanism of the new polymer is different from that of the traditional polymer. As a type of dispersion displacing phase liquid, the new polymer can dynamically modify the permeable ability of different areas, by which the oil and water mobility can be modified effectively, achieving the aim of enhanced oil recovery.
The studies preliminarily established the property evaluation method for particle-type polymer, and discovered the IOR/EOR mechanism of the new particle-type polymer. The pilot test conducted in a reservoir with high temperature, 120 °C, and high salinity, 14.9-21.7×104 mg/L, with Ca2+ / Mg2+ concentration of 2500 mg/L, obtained obvious oil rate increase and water cut decrease effect, and achieved technical and economical success.
Novel Workflow for the Development of a Flow Control Strategy with Consideration of Reservoir Uncertainties
Authors: Gohari Kousha , Jutila Heikki , Mascagnini Carlos , Gryaznov Andrey , Goodwin Nigel , Howell Murray , Kidd Peter J. , Bijani Behrooz 
Published: November 2015

Abstract
Flow control along the wellbore is an important factor for a successful field development. Creating a flow control strategy can be especially difficult when a high level of reservoir uncertainty exists.
A novel workflow was developed to help determine the flow control / intelligent completion strategy best suited for field development, by taking into account the reservoir uncertainties and control parameters for optimization. The workflow simplifies and reduces cycle time, yet ensures that the inflow control strategy for the field is fit-for-purpose. This novel methodology enables a rapid understanding of the uncertainties and reduces the cycle time of evaluation and high-level screening, and ensures a more responsive decision process to improve production and reduce costs.
The described workflow is an optimum approach that is easily applied in an efficient semi-automated manner for any field. This method utilizes steady-state analytical and dynamic reservoir modelling for the determination of geological/subsurface uncertainties and selection of an optimal flow control strategy. Initially a base case model is constructed with the most likely/expected reservoir properties and control parameters. A series of experimental design cases are run, and then an objective function is created, followed by a large number of optimization runs to investigate the potential solution space. The analysis of these cases quantifies the effects of each uncertainty parameter. Using the analysis performed on uncertainty, a number of the scenarios are investigated in detail to study various flow control completions (passive and active) and determine the system that is best suited to achieve the optimum recovery efficiency. A full optimization under uncertainty is conducted so that the flow control settings are optimized against the full probabilistic subsurface uncertainties.
Enriched Inflow Performance Relationship (EIPR) Curves for Simultaneous Selection of Target Rate & Pump Setting Depth While Visualizing Free Gas Conditions
Authors: Caicedo Sergio 
Published: November 2015

Abstract
During the pump sizing, artificial lift (AL) engineers usually deal with the problem of deciding the setting depth of the pump and the target production rate. There is a trade-off regarding the pump's depth; the deeper the pump, the lower the free gas, the higher the potential rate, the higher the submergence but the higher the cost, and the higher the temperature. The present paper shows a method to suggest setting depth and target rate simultaneously.
Sometimes there are so many constraints that the setting depth is imposed by the reservoir, well completion, integrity or safety conditions. In other circumstances, there can be a wide range of possibilities, which will be discussed in this paper. One of the most important parameters to evaluate is the free gas into the pump because it will greatly affect the performance of the pump, besides requiring more volume capacity, the free has other consequences such as locking the ESP, affects the PCP elastomer, reduces the compression ratio in SRP and increases the required power fluid pressure and/or rate in JP. The free gas limits and solutions vary for each method, but all of them require knowing the actual value, independently of the pumping method (i.e. ESP, PCP, SRP or JP). The engineer has to start by imposing the pump's depth and after some computations check if that depth is feasible or not for the target rate. If it is not feasible two actions can be done: to reduce the target rate and/or to install the pump deeper. On the other hand, if the pump can handle the free gas then a question arises: could the pump be installed shallower keeping the same target rate? This question can only be answered by computing free gas and displaying it in some way together with the reservoir inflow.
In order to avoid this trial and error process, this paper defines and suggests the Enriched Inflow Performance Relationship (EIPR) curves at pump intake for different setting depths, each one showing points highlighted using a colour scale to indicate free gas conditions into the pump. The free gas displayed mainly depends on the Pump Intake Pressure, Bubble Point Pressure, GOR, Water Cut, downhole gas separation efficiency. Since the reservoir performance is included, these EIPR Curves easily allow simultaneous selection of target rate and pump setting depth while visualizing free gas conditions which avoids the trial and error process showing a more realistic application window of the method.
All previous papers just display standard inflow curves. There is no previous work showing additional attributes in the IPR curve that helps the engineer to visualise the corresponding conditions of the pump.
Maintaining Aging Export Systems - Replace, Maintain or Renew?
Authors: Collins Jonathan , Morvan Remi , Whelan Tim 
Published: November 2015

Abstract
Offshore Loading Systems represent a critical asset of tank farms and refineries operations, with potentially significant financial consequences in case of unavailability.
The paper looks at the main issues associated with Integrity Management of aging export and loading systems (both topside equipment such as CALM buoys and subsea equipment such as pipelines and PLEMs) and discusses the main drivers forcing Operators to consider either replacing or upgrading their existing systems.
Following a steep decline in oil prices at the end of 2014, which are likely to remain at present values for the near future, many Operators are looking at options to postpone planned procurement projects to replace aging equipment and are pursuing alternative strategies to maintain the output and uptime of their aging facilities. This paper discusses Integrity Management best practices, available to Operators to survey and maintain as well as manage the service life extension of their systems.
The paper also addresses the options available when remediation works must be carried out. In particular, attention is focused on novel refurbishment activities which can be performed onsite whilst minimising the level of system downtime. Examples include: Refurbishment of CALM Buoys in dry-dock or on-site, relining of corroded subsea pipelines and removal/replacement subsea of damaged or corroded sections of pipeline.
In conclusion, a number of cost comparison studies are presented to demonstrate the potential financial benefits of extending the remaining life of a system rather than replacing aging equipment with new.
An Example for Successful Integration of Borehole Seismic Technology in Exploration and Development
Authors: Lange Christian , Katsuko Suzuki 
Published: November 2015

Abstract
Borehole seismic surveys provide vital depth and velocity parameters needed to link surface seismic data with downhole log and well data. Furthermore they can deliver high-resolution subsurface images, detect anisotropy caused by natural fractures and help to monitor fluid movement depending on the chosen survey geometry.
A borehole seismic survey, whether simple checkshots or a more complex VSP, is usually part of the initial data acquisition program in exploration and appraisal wells, but it is not uncommon that only the depth-time data from such a survey is used in seismic interpretation. This paper is intended for geoscientists working on subsurface projects to highlight information that can be gleaned from a VSP wavefield in addition to only a depth-time correlation.
Delivering a Compliant Composite Solution in a Noncompliant Situation
Authors: Johnson Peter , Oharriz Osmay 
Published: November 2015

Abstract
This paper discusses about two-part composite systems consisting of thermoset epoxy resins reinforced by carbon and glass fiber for applications onto pipeline, pipework, piping systems, and vessels in pressurized service. The document presents details related to qualification and testing of such systems in compliance with internationally accepted standards. It also covers key components of a composite repair from the application standpoint and describes what is required to deliver a compliant solution from inception to final inspection.
Composite repairs are rapidly becoming an acceptable maintenance option even for safety critical equipment because they repairs offer an engineered, durable, and affordable solution. Additionally and more importantly they comply with international engineering standards. Designed for application onto pipelines, pipework, and pressurised vessels, composite repair systems are typically composed of resin and reinforcement sheet.
Pipeline is the pipe or components, including bends, flanges, valves, and reducers among others, used to transport fluids between plants. Hence, pipelines are generally long and of larger diameters. Piping is the pipe or plurality of pipes, joints, valves, gaskets, fittings, etc., used for transporting fluids within a plant, and they can be above or below ground. Other pieces of equipment where two-part component composite repairs can be used include pressurized vessels and tanks, and/or some of their components such as saddles, main body connections, supports, nozzles, and tees among others.