bluuebunny/crossref_metadata_2025_split huggingface dataset:
Online Condition Monitoring System Identifies Developing Faults in Reciprocating Compressor at the Very Outset
Authors: Qureshi Fayyaz Karim , Bickmann Thorsten 
Published: November 2018

Abstract
Safety of personnel, assets and environment has been an essential priority for most operators and there has been an ever-increasing emphasis from EHS authorities to improve systems to be able to trip automatically and save assets from any catastrophic failures. Like any other critical equipment, an online monitoring and protection solution has become inevitable for reciprocating compressors to address this requirement.
Additionally, inclination of operators towards proactive maintenance strategies instead of conventional preventive maintenance practices has prompted the need of an online condition monitoring solution that can provide insights into the condition and performance of machines. Instead of overhauling reciprocating compressors every 18-24 months and replacing all components as part of preventive maintenance, systems are able to pinpoint any developing faults within machines at an early stage; helping operators to plan outages, to arrange optimized spares timely and replacing only failed components with minimal downtime; ultimately justifying return on investment (ROI).
API recommendations for protecting reciprocating compressors have developed over the years. In 2007, API 618 5th Edition was released where only crankcase/frame vibration was recognized as minimμm requirement for protecting reciprocating compressors from a vibration monitoring system's perspective. Then a series of failures on several reciprocating compressors globally influenced API 670 to include crosshead vibration to protection matrix in 2014. The advancements and enhancements in solutions did not end there. Continuous improvements in data acquisition systems and vigilant analysis have identified certain additional parameters equally significant to identify developing faults in running gear and have been found efficient in protecting machines before the faults turned into failures; piston rod peak-peak displacement being one of those.
This paper describes comprehensive instrumentation required for condition monitoring of reciprocating compressors and delineates through case histories, how system was able to pinpoint failing components at early stages consequently saving machines from catastrophic expensive failures.
Use of Miniaturized Sensors to Optimize Cleaning Operations for In-Line Inspection of a Subsea Pipeline
Authors: Di Lullo Alberto G. , Passucci Claudio , Hester Keith C. , Zaffaroni Raffaele , Reinhart Robert 
Published: November 2018

Abstract
Pipeline in-line inspection requires a proper cleaning of the pipeline inner walls. In the case hereby described of a 30km 12" offshore line, a significant amount of wax deposits was expected and a series hydro-mechanical cleaning tools were deployed, after a preliminary series of less aggressive pigs.
Normally, the progress of the cleaning process is monitored only by the arrival conditions of the cleaning tools and of the receiving trap. To improve the process, miniaturized pressure, temperature and acceleration sensors were added to the cleaning tools, directly in the field, without any modifications to the cleaning devices and without introducing any additional risks or operating impact. After each instrumented cleaning tool, the sensor data were quickly analyzed and led to the selection of most suitable subsequent tool.
In this way, it was observed that the pig conditions and the amount of material collected in the receiving trap did not fully indicate the true cleaning status of the pipeline, while the sensors provided a clearer picture. The pig sequence was thus optimized in number and type of pigs and the intelligent pig run was preformed successfully with no issues or data loss.
The advantage of these tiny sensors, not foreseen in the hydro-mechanical pig design, is that they can be applied to almost any pig with minimal-to-no modifications. This information can be used in a number of ways, including detection of flow restrictions (dents, deposits), and can also be used to re-create the line elevation, profile with limited a priori information.
Measurement of Propane and Butane Diffusion into Heavy Oil using Microfluidics - Is Small Better?
Authors: Zhao Hongying , Pierobon Scott , Pettigrew Adam , Doan-Prevost Jacques , Garnier Olivier-Francois , de Haas Thomas 
Published: November 2018

Abstract
The high energy intensity of steam-based heavy oil extraction processes is leading the industry to investigate solvent-aided processes for heavy oil/bitumen recovery. The diffusion coefficient of solvent in heavy oil is a key parameter to determine how effective these processes are. Measuring the diffusion coefficient is challenging, especially at in-situ conditions, i.e., at elevated temperature and pressure. This paper presents a microfluidics-based method for measuring the diffusion coefficient of propane and butane, the most commonly used light hydrocarbons in solvent process, into heavy oil at high temperature and pressure conditions.
A silicon-glass microfluidic chip was designed and fabricated using the Deep Reactive Ion Etching (DRIE) and anodic bonding. The diffusion tests were performed at temperatures ranging from 20°C to 120°C and pressures up to 100 bar. Upon blue light excitation, heavy oil naturally fluoresces at visible wavelengths, and the intensity varies with solvent concentration. Based on this mechanism, the light intensity change of the heavy oil in a 100-micron channel was recorded with a camera connected to the microscope during the diffusion process. An image processing method was developed accordingly to create a map of fluorescence light intensity versus diffusion time and distance, which was further processed numerically to calculate the diffusion coefficient with measured correlations between light intensity and solvent concentration.
At all testing conditions both solvents were liquid which inevitably would cause asphaltene precipitation at oil-solvent interface as demonstrated by the observations during the diffusion tests. It was also found that the asphaltene precipitation phenomena were more pronounced with butane than propane. To measure the diffusion coefficient, a method using solvent diluted oil was developed to avoid the asphaltene precipitation issue.
The measured diffusion coefficient of propane was around 0.6 × 10-10 m2/s using pure solvent method, and that of butane was in the range of 1—9 × 10-9 m2/s, at their corresponding testing conditions. For both solvents the diffusion coefficients increased with temperature while no satisfactory trend was observed with pressure within 100 bar.
Automatic History Matching Theory, Implementation, and Field Applications
Authors: Arroyo Negrete Elkin , Rodiguez Jose , Goryachev Sergey , Belova Natela , Al Blooshi Ahmed , Basioni Mahmoud 
Published: November 2018

Abstract
History matching (HM) is a mandatory step for any reservoir simulation study. Without a proper history match, a reservoir simulation model may lose credibility, or even worse, may lead to erroneous conclusions. HM is typically approached by reservoir enginners (RE) using a trial and error method, but there is a new, more advanced methodology known as computer assisted or automatic automatic history matching. Although assisted HM technology is well developed, its acceptance in the RE community has been slow. This paper aims to explain the concepts in a simple manner and suggest practical tips to make it easier for a practitioner to use automatic HM technology properly.
First Nitrified Managed Pressure Drilling Application in United Arab Emirates
Authors: Almetayev Rakhat , Al Hosani Muna , Al Ameri Saleh , Al Mutawa Ahmed , Ahmad Hussain Mushtaq , Abraham Jobin , Saleh Mujahed , Hadj-moussa Ayoub , Pham Dang Le Khoa 
Published: November 2018

Abstract
Drilling fluid losses while drilling a mature cretaceous limestone reservoir unit (Formation A) has been worsening over years with reservoir depletion and lack of pressure support. New drilling methods were needed to eliminate or reduce total losses and the associated non-productive time with them. Nitrified Managed Pressure Drilling proposed to help in mitigating losses and reducing non-productive-time. This paper explains the challenge, details the solution that was proposed to tackle, and discusses the results of the application.
Nitrified Managed Pressure Drilling (MPD) decreases the Equivalent Circulation Density (ECD) below the lowest possible static mud weight (water) and at the same time deals safely with any unintended hydrocarbon influxes while drilling the reservoir 6″ hole section. The well data was analysed and modelled with different Nitrogen pumping rates and Surface Back Pressure (SBP) to determine the best rates that a mitigates losses but at the same time prevent hydrocarbon influxes. A closed-Loop drilling system proposed utilizing rotating control device, a separation package, and locally produced membrane Nitrogen allowed to manage the annular hydraulic pressure profile accordingly and mitigate the total losses scenario eliminating the wait on water time
Rigorous planning and disciplined execution have led to safe and successful conclusion with no QHSE issues encountered. The designed Nitrified Managed Pressure Drilling solution succeeded in preventing the drilling fluid losses in the reservoir section by reducing the overbalance pressure of the drilling mud from 700 psi to 250 psi, which resulted in the elimination of 3 days of the rig's non-productive-time related to waiting on water. The closed-loop system coupled with a precise data acquisition and monitoring system has helped in maintaining a slight overbalance condition over the reservoir preventing any unintended hydrocarbon influxes to the surface. The lessons learned captured from this operation have contributed to the optimization of the Nitrified MPD in (Formation A) and to the overall MPD implementation in ADNOC fields.
This paper displays the first application of nitrified managed pressure drilling in the United Arab Emirates. The equipment design and planning have accounted for many different scenarios, as this type of drilling technology enables more precise wellbore pressure management with less interruptions to drilling ahead
Experimental Investigation over Effect of Geometrical Changes on Gas/Liquid Cylindrical Cyclone GLCC Separator
Authors: Asaadian Hamidreza , Soltani Soulgani Bahram , Rezaei Gomari Sina , Soltani Soulgani Bahador 
Published: November 2018

Abstract
Gas and liquid outlets length Study and its effect on Gas/liquid Cylindrical Cyclone (GLCC) separator performance. Gas body column length Study and its effect on GLCC separator performance. Inlet diameter Study and its effect on GLCC separator performance. Study of body column diameter and its effect on GLCC separator performance. Study of gas and liquid outlets diameter and its effect on GLCC separator performance.
An experimental GLCC separator was designed and built in laboratory to determine its domain. The best operational domain is where the equilibrium liquid level placed below the inlet and between 1 L/D and 3 L/D of separator column. If it pass the inlet it causes liquid carry over and if it settles below the 3 L/D it creates gas carry under in the separator. Thus the equilibrium liquid level was measured for different range of liquid and gas flowrates. In this work the gas superficial velocity was set between 0.3 and 6 meter per second and for each gas superficial velocity, liquid superficial velocity was from 0.3 to 3.3 meter per second. Moreover, different parts of test separator was changed and their effects on the separator operating domain was studied. These changes are 12.7 mm reduction in inlet diameter size, 5 mm reduction in liquid outlet diameter size, 5 mm reduction in gas outlet diameter size, 0.12 meter reduction in gas column length, 25.4 mm reduction in column diameter size and 1.4 meter increment in outlet length.
Based on this work the following results were obtained:Reducing the inlet diameter improves the GLCC separator performance. It allows more gas and liquid flowrates enter the separator for total separation by enhancing the centrifugal effect on liquid and gas phases.Reducing the liquid outlet diameter has negative effect in GLCC flowrates domain but this reduction can be used to control the equilibrium liquid level by a gate valve in liquid outlet leg.Reducing the gas outlet diameter has negative effect on GLCC performance. But in some situations controlling the amount of accumulated gas in GLCC can avoid liquid carry over in the system.Reduction in gas column length shows no effect on the separator flowrates domain.Increasing in length of outlet legs increases the friction force and limited the separator performance.Reduction in separator body diameter raises the chance of liquid carry over and gas carry under and has negative effect on flowrates domain.
These findings from GLCC performance give the main guideline to design more efficient separator design for oil and gas fields. Proper designing makes separator performance domain wider whereas it creates separators more compact which in turn minimizes the cost of construction accordingly.
Characterising and Defining Stimulation Zones in Tight Formations for Appraisal Wells Onshore U.A.E with the Aid of Integrated Standard and Novel Stress Determination Methods
Authors: Doucette Neil , Ziller Matthias , Addis Tony 
Published: November 2018

Abstract
Several onshore concessions, currently under exploration by ADNOC, consist of tight laterally variable reservoirs that pose a significant challenge during the evaluation phase of exploration.
Most tight hydrocarbon-bearing formations require fracture stimulation. As such, the evaluation phase of these resources comprises not only the characterisation of reservoir rock properties using petrophysical analysis but, crucially, the construction of 1-D Mechanical Earth Models which underpin the identification of stimulation intervals for both vertical and horizontal well completions. The 1-D MEMs discussed here were provided by different vendors and have been calibrated against interval pressure tests, that included standard "wet" straddle packer microfractures and novel "dry" Sleeve-Fracture tests. The microfracture test data used to calibrate the MEMs were obtained from different depth intervals in onshore Abu Dhabi E&A wells and exhibit non-ideal pressure decline "shut-in" behavior. This required re-analysis using different interpretation methods to identify the lower bound fracture closure pressures and minimum stress magnitudes.
The identification of stimulation intervals from the 1-D MEMs highlighted the uncertainty in the minimum stress magnitude estimations from both the log-based models, and the microfrac interpretations. The uncertainty in the log-based minimum horizontal stresses can exceed 0.15 psi/ft (&gt;17%), even after calibration with the microfracture tests. The uncertainty in the fracture closure pressure obtained from the microfracture test can also be as large as 1,600 psi (0.22 psi/ft and 30%).
The identification of the sources of the uncertainty, their quantification and the re-evaluation of microfracture tests fed directly into updated 1-D MEMs, which led to improved recommendations for optimised injectivity tests and acid fracturing treatments. This, in turn, has translated into a successful fluid sampling and production appraisal programme.
Tailored 9 5/8–in. x 12 1/4-in. Single Piece Centralizer with High Restoring Force for Challenging ERD Wells in UAE
Authors: Bermudez Alvarado Romulo , Navas Luis , Mahamat Habib Abdelkerim Doutoum , Al Katheeri Yousif , Krieger Sebastian , Kiess Christian , Farley Douglas , Mostafa Khamis , Shaker Sherif , Khallaf Ahmed , Rajadhyaksha Sachin 
Published: November 2018

Abstract
This paper describes how the unique centralizer requirements for extended reach drilling (ERD) wells can be attained. By continuously evaluating past casing runs in combination with engineering input, the learning curve led from a standard centralizer to a highly customized solution. The necessary flow path target to enhance the wellbore isolation through cement placement is met by achieving the right centralizer performance and placing.
A single-piece high-restoring-force centralizer is the best solution for the high inclination well profile to obtain the required 9 5/8-in. casing stand-off for ERD wells.
The original centralizer design experienced challenges such as high doglegs in some of the longest 9 5/8-in. casing strings that have been run in the UAE to date. Customize the centralizers for different well profiles was necessary. They were developed and tested according to the latest API 10D (2001) specifications using precision equipment to ensure reliable test results that enable accurate hook load and stand-off simulation.
Initially, a standard off-the-shelf design of a 9 5/8-in. x 12 1/4-in. single-piece centralizer was used in two wells with the following results:Friction factor exceeded the expected values across the interval on occasion.Total Depth (TD) was sucessfully reached by washing down to bottom.Good centralization as per software design was attained (tageting 80%) with moderate to good isolation.
Due to the performance, while running in the hole (RIH), concerns arose due to the unexpectedly high friction factor which, could lead to difficulties RIH and reaching TD in future wells. The modified centralizer design has led to the following improvements:Reduction of friction factor to an average of 0.24 due to a significant decrease in the centralizer running force even through reduced hole diameter intervals and the high dogleg severities (DLS)Reaching TD successfully.Stand-off remained around 80%, as demonstrated by outstanding cement bond log results across the critical sections.
It is important to consider that this centralizer was designed not to lose any performance after being run through reduced hole diameter intervals. The application of enhanced centralization design (i.e., standoff &gt;80%) ensured good quality of the cement job.
Soft Computation Application: Utilizing Artificial Neural Network to Predict the Fluid Rate and Bottom Hole Flowing Pressure for Gas-lifted Oil Wells
Authors: Bahaa Mazen , Shokir Eissa , Mahgoub Ismail 
Published: November 2018

Abstract
The fluid rates and bottom-hole flowing pressure of the wells are essential parameters in the petroleum industry. The need of accurate readings of these measurements are necessary for many calculations such as gas-lift optimization, field monitoring and depletion plans. Predicting these parameters without running in hole has a good impact on reducing the intervention risk and on organization financials by saving time and money. Huge number of correlations are used to estimate these parameters. These correlations need the values of different parameters that are not accurately found. Therefore, an artificial neural network (ANN) model was built from exported data set of PROSPER1 software, production logging tool (PLT), and test separator data. The ANN model was trained and tested by the PROSPER1 extracted data. Then, a number of test points gathered from the PLT reports validated the ANN model. The developed ANN model results in an accurate prediction of the well flowing bottom-hole pressure and well fluid rate. These readings of each well are used to build an integrated production model (IPM) using GAP2 software to apply different gas-lift optimization scenarios.
Development and Testing of an LWD Ultrasonic Microimaging Tool: Field Test Results from the Middle East and Europe
Authors: Warot Gregory , Wallace Shawn , Mostafa Hassan , Elabsy Eslam , Di Tommaso Davide , Abdelkarim Aly , Ciuperca Constantin-Laurian 
Published: November 2018

Abstract
Increased development of naturally and hydraulically fractured unconventional reservoirs from horizontal wells, drilled with oil-based muds, has created a need for high-resolution logging-while-drilling (LWD) borehole imaging tools capable of resolving fractures in this borehole environment. A new LWD ultrasonic borehole imager has been developed and tested to meet this need.
Borrowing from wireline ultrasonic imaging technology, a 250 kHz piezo-electric transducer was adapted to an LWD drill collar. The single transducer serves as both transmitter and receiver: transmitting an ultrasonic pulse, and measuring both the amplitude and two-way travel time of the acoustic reflection from the borehole wall. The LWD tool takes advantage of drill string rotation making a 360-degree scan of the borehole with a single fixed transducer. Finite element modeling and laboratory testing in artificial formations and a large limestone block were used to determine the spatial resolution of the image, as well as the sensitivity to downhole acquisition variables such as standoff, tool eccentricity, and mud attenuation. Prototype tools were then field tested in several horizontal wells to verify the functionality and image resolution under actual drilling conditions.
The borehole images from horizontal wells in unconventional and conventional reservoirs in the Middle East and the UK verified that tool responded as designed. These images, recorded in both oil-based and water based muds, revealed open and cemented natural fractures, drilling induced fractures and borehole breakout, fine-scale bedding, and other textural geological features such as vugs and stylolites. A variety of drilling-related borehole artifacts were also observed, including keyseats, stabilizer impressions in the borehole wall, tool marks from a rotary steerable tool, and gouges made by the bit rotating off bottom. The amplitude image proved more sensitive to fractures, bedding, and other geological features, while the travel time image, combined with input mud compressional velocity, provided a 360-degree borehole caliper image, showing the borehole size and shape.
Although high-resolution LWD electrical imagers have been available for years, these can only operate in conductive, water-based, muds. As most horizontal wells in both conventional and unconventional reservoirs are now drilled with oil-based muds, the development of a high-resolution ultrasonic imager capable of identifying natural and hydraulic fractures, fine-scale bedding, secondary porosity, and other small scale features in wells drilled with oil-based muds fills an important gap in LWD technology.