bluuebunny/crossref_metadata_2025 huggingface dataset:
Deep Learning for a Fast and Accurate Prediction of Complex Carbonate Rock Permeability From 3D Micro-CT Images
Authors: Tembely Moussa , AlSumaiti Ali
Published: November 2019

Correctly predicting subsurface flow properties is critical in many applications, ranging from water resource management to the petroleum industry. In the present paper, we establish a workflow to apply machine and deep learning (DL) to quickly and accurately compute petrophysical properties based on micro-CT images without any computationally intensive procedures. The pore network modeling (PNM) approach is widely used for fast computation of flow properties, albeit with less accuracy due to the inherent simplification of the pore space. Alternatively, direct simulation, such as the lattice Boltzmann method (LBM) is very accurate; however, its high computational cost prevents this approach from including all the relevant flow physics in a single simulation. After assessing numerical techniques ranging from PNM to the LBM, a framework based on machine learning (ML) is established for a fast and accurate prediction of permeability directly from 3D micro-CT images of complex Middle-East carbonate rock. We use thousands of samples from which engineered features—based on pore network modelling and images analysis—are fed into both shallow and deep learning algorithms to compute, as an output, the permeability in an end-to-end regression scheme. Within a supervised learning framework, algorithms based on linear regression, gradient boosting, support vector regression, and convolutional neural networks are applied to predict porous rock petrophysical properties from 3D micro-CT images. In addition, a hybrid neural network accounting for both the physical properties and 3D raw images is investigated. Finally, the estimated permeability of a complex carbonate by ML is found to be in good agreement with a more intensive simulation by voxel-based direct simulation. Furthermore, a significant gain in computational time—approximately three orders of magnitude—is achieved by applying ML compared to the LBM. This work highlights the critical role played by features engineering in predicting petrophysical properties using DL. The proposed workflow, combining deep learning and rock imaging and modeling, has great potential in reservoir simulation and characterization to swiftly and accurately predict petrophysical properties of porous media.
NGPD Roadmap to Lubrication Excellence
Authors: Nadeem Tariq
Published: November 2019

Reliability engineering unit conducted comprehensive and detailed study of machinery lubrication systems for salt water injection pumps and gas compressors operating at various facilities of north Ghawar producing department of Saudi Aramco to achieve lubrication excellence.

As a part of lubrication study, data from the following sources was collected, analyzed and gaps were addressed for better contamination control to enhance equipment reliability and compliance KPI. 2017 corporate lubrication KPI report issued by CSD.Benchmarking between NGPD and ShGP Department.RU field assessment during 3rd quarter of 2018.

Study reveals that improper sample collection, oil mixing, improper sampling point, old fashion breather design, insufficient operator's knowledge and skills set and unavailability of lubricant cleaning services are key identified areas which were addressed and proper corrective actions were implemented through management of change process. As the result of partial implementation of conducted study, we have achieved 92.25% compliance target in second quarter of 2019 which is very good success rate of indicating positive trend with the cost saving of Cost saving of $112,844.
Efficiency of High Power Laser in Carbonate Formations
Authors: Othman Haitham , San Roman Alerigi Damian , Batarseh Sameeh , Al Obaid Omar
Published: November 2019

The objective of this work is to utilize high power laser technology (HPL) for two downhole applications in carbonate formations including perforation and fracture initiation. This is critical because current technologies for perforation cause compaction and reduce the permeability around the perforated tunnel. Furthermore, initiating fractures in tight carbonate formations requires high breakthrough pressures, which leads to additional damages and costs. HPL technology is a contactless and waterless alternative for these applications in any kind of rock; earlier laboratory results showed that the technology improves permeability, increases porosity, enhances the mechanical structure of the rock, and reduces damage to the neighboring formation. This work investigates some of the physical and chemical changes induced by high power laser on carbonate rocks.

A high power laser system is used to perforate and heat different types of carbonate rocks. These include some limestone and dolomitic samples of different shape and size. The rocks are characterized before and after the process using a combined multi-physics and multi-scale approaches. Small core plugs and cuttings are used to study the effect at micro-level. Larger samples are used to characterize the effect of the overall structure of the rock. The chemical transformations are captured using differential thermal analysis (DTA) and X-ray diffraction and fluorescence (XRD/XRF). The laser interaction is recorded in real-time using high-speed infra-red thermography.

Experimental results illustrate how the high power laser can create long and wide perforation tunnels in carbonate rocks. Micro-level observations evince that the permeability increase due to the creation of micro-fractures and changes in interconnectivity between the pores. Large-scale measurements show that high power laser can controllably weaken the rock within the heat-affected zone, enhance porosity, and increase permeability. These changes can improve the fracture initiation process in these rocks. The analysis of the laser-rock interaction also shows that the laser induces a calcination process that dissociates the calcium carbonate into CO2, lime, and other compounds. This may have a positive effect on the overall energy balance of the process.

This work demonstrates that high power laser can be used to enhance the perforation and fracture initiation processes in carbonate rocks. The technology can controllably create tunnels of different sizes and lower the compressive strength of the rock; consequently, it reduces the pressure needed for fracture initiation. The multi-scale and multi-physics analyses presented in this paper provide a comprehensive overview of the process and its implications for downhole applications.
Monetization Opportunity in Gas Processing Facilities by CO2 Recovery
Authors: Vyas Ajay
Published: November 2019

The objective of the study was to assess monetization opportunity in existing gas processing facilities by recovering CO2 from the acid gas stream and utilizing it to enhance oil recovery. This could potentially lead to generating more revenues with minimum modifications and optimizing the plot footprint, energy, and overall cost, all while maintaining business continuity.

The Study was conducted in two stages:

Feasibility Study was carried out to identify a potential site location and UTC per ton of potential recovered CO2 to meet pilot phase EOR requirement of upstream oil facilities. Study recommended to recover CO2 from existing AGRU Regenerator overhead using chemical solvents, TEG dehydration and compression. Pre-Feed Study – The developed idea along with other potential options were thoroughly evaluated by a Pre-FEED Study to select the most techno-economic viable location, technologies and overall process configuration in order to capture CO2 to meet upstream oil company pilot phase requirements for EOR.

The final selected concept for CO2 capture was as per followings:

Low pressure chemical solvent type CO2 capture Unit located downstream of the AGRU but upstream of the flash / recovered flare gas tie in; Wet CO2 compression to TEG dehydration unit and dry CO2 compression transport for injection; Reinject enriched H2S from the CO2 capture unit to condensate reservoir The selected concept UTC US$ / MT of CO2 compared by performing similar exercises for other two sites and it is observed that UTC varies depending on existing process and utilities systems configuration, feed gas quality and product specifications.

Concept of recovering CO2 from existing oil & gas facilities for EOR facilitates minimizing CO2 emissions and its footprint.

This concept can potentially be enhanced by taking calculated risks and applying emerging technologies with Licensors’ to ease UTC from its current level and complement other by-products to enhance overall value chain in energy sector. In addition to that this, UAE has set the National Climate Change Plan 2017–2050 that serves as a roadmap to boost nationwide actions for climate mitigation. Capturing CO2 for EOR economically will facilitate UAE to minimize carbon emission footprint.

Based on aforementioned Pre-FEED study, this paper identifies and evaluates the most viable options for the CO2 capture unit location, CO2 capture technology, CO2 dehydration and transport technology and H2S handling for the entire operating envelope. This paper also provides an overview of the CO2 dehydration unit optimum operating pressure, discussions on CO2 wet and dry compressors and the configuration of the CO2 capture train(s).
Micro Porosity within the Organic Matter and its Impact on Assessment of Unconventional Potential of a Kerogen Rich Najmah Formation in Kuwait
Authors: Mishra Prasanta , Grader Avrami , AlJallad Osama , Kayali Anas
Published: November 2019

Carbonate reservoir rocks of the Najmah formation in Kuwait, with low porosity and low permeability, have been characterized using integrated digital and physical rock analyses methods. High-resolution imaging and analyses determined the microstructural characters of mineral matrix, organic matter (OM) distribution, organic and inorganic pore types, size distribution, and permeability variation within this kerogen-rich Late Jurassic stratigraphic unit.

Considerable heterogeneity of porosity and permeability was observed in the 100-ft studied interval of the Najmah Formation. Two-dimensional scanning electron microscopy (2D-SEM) imaging and three-dimensional focused ion beam SEM (3D-FIB-SEM) imaging highlighted the different types of porosities present within the formation rock. At each depth, several 2D-SEM images were used for characterization and selection of representative locations for extracting 3D FIB-SEM volumes. The 3D volumes were digitally analyzed and volumetric percentages of OM and total porosity were determined. The porosity was further analyzed and quantified as connected, nonconnected, and associated with organic matter. Connected porosity was used to compute absolute permeability in the horizontal and vertical directions in the area of interest.

Porosity associated with OM is an indicator of OM maturity and flow potential. It has been categorized as pendular type, spongy large grain, spongy small grain, fracture porosity within the OM, grain boundary fractures and intergranular porosity covering the entire OM. Permeability is not only influenced by porosity within OM or even apparent transformation ratio (ATR), it is also dependent on pore connectivity, pore sizes, and heterogeneity (e.g., high-permeability streaks). For high porosity samples, almost all pores are connected and contributing to permeability. For low porosity samples with high permeability, the flow is mainly through microfractures. It is possible that intergranular clay pores in highly thermally mature rocks were originally filled with OM and that, during progressive thermal maturation, transformation of OM to hydrocarbon(s) removed much of the pore filling OM.

It has also been observed that, although the total organic carbon (TOC) content of the rocks is significant (up to 18 wt%), and good maturity index (VR0>1), only few examined samples show good connected porosity within the OM. It is essential to evaluate the porosity within the OM thorough high-resolution measurements for pinpointing the prospective layers for future stimulated horizontal wells in this organic-rich source unit. These intervals can be considered as the potential sweet spots after integration with detailed petrophysics and geomechanical parameters for optimized well planning and completion design.
Air Cooler Vibrations - Amplified Amplitudes, Simplified Solutions
Authors: Al Awadhi Ibrahim , M. Sharma Ashok , Subramaniam Krishnan , Al Zeyoudi Saleimah
Published: November 2019

Objective/Scope

One of the largest Air-cooled steam condensers in our plant having 16 bays & 32 fans of 4.8m diameter, was observed with high vibrations beyond 100 mm/s, resulting in equipment integrity & HSE concerns. Most importantly, 250 MT/hr of steam has to be vented to atmosphere, if the air-cooler is down. This paper presents the alternate approach adopted which resolved vibration issue, enhanced availability & improved steam system efficiency, with simple but robust solution.

Methods, Procedures, Process

Performed meticulous measurement of Aircooler vibration spectrum, which includes frequency, amplitude, velocity & structural natural frequency. As motor solo-run test confirmed no inherent vibration originating from motor, analysis was imperative to find the root cause. Hence, developed ANSYS model of existing Aircooler to simulate different modes & corresponding frequencies. Analysis confirmed that high vibration was a result of resonance between structure natural frequency and motor/blade pass frequency.

Results, Observations & Conclusions

The results from detailed study and analysis recommended that in order to eliminate the resonance criteria, number of fan blades has to be changed from 11 to 12 and enormous amount of additional structures / bay to be added to shift the structural frequency away from its natural frequency. Total estimated cost of execution for this option is ~1 million USD for all 16 bays and require aircooler shutdown.

Instead of the above ceremonial solution, a simple and easy to implement, analytical solution was recommended to locally stiffen the motor & gearbox support plates. This would minimize the vibration amplitude, reduce fatigue loading and enhance structural rigidity & integrity. The cost of this option is negligible as the modification does not involve major changes and can be executed with in-house resources. Primarily, this option can be executed without the need for Aircooler shutdown.

The alternate solution has been implemented and the vibration levels have reduced considerably, ensuring aircooler Integrity. Most importantly, this approach has improved aircooler availability and avoided venting of 250T/hr of LP steam, costing ~24K USD/day.

Novel/Additive Information

Vibrations in aircoolers not only causes HSE & integrity concerns but their unavailability leads to steam letting off. The detailed analysis and robust solution has not only improved integrity, but also avoided huge structural modification & associated cost, improved availability, eliminated steam letting down and thus enhancing steam system efficiency.
Near Real-Time Corrosion Monitoring for Wellbore Integrity Management
Authors: Kumar Amit , Al Daghar Tareq , Al Shehhi Ali , Keinath Brendon , Kulkarni Mohan , Beltramino Pedro , Long Andrea
Published: November 2019

For safe operation of wells, it is critical to maintain the integrity of production tubing. Integrity management in the wellbore needs to address a variety of factors including exposure to harsh environments, accessibility limitations on inspection tools, cost-optimization and need for production interruption for running the downhole inspection tools. Such scenarios make regular corrosion measurements difficult, and can result in a reactive approach to integrity management. Corrosion prediction software provides a solution to alleviate this issue.

Water-chemistry and flow parameters are key drivers for corrosion assessment. Generating these inputs for corrosion predictions using industry standard flow models requires significant expertise and is tedious which limits the frequency of assessments. Given the significant number of carbon steel tubulars in a giant offshore oil field in Abu Dhabi, the original process was too cumbersome resulting in only a select number of wells being modeled. To streamline the process, an automated application was developed which virtually integrates wellbore mapping, field data, multiphase flow physics, water-chemistry, and proprietary corrosion modeling software seamlessly.

The corrosion monitoring application has allowed for more frequent and timely corrosion assessments of a significant number of wells. The results to date include optimization of corrosion inhibitor (CI) usage during early production and to drive decisions for timely CI squeeze treatments. In addition to CI optimization, the high fidelity corrosion predictions have also driven preventative mitigations in wellbores with high wall loss leading to improved integrity. Application of this tool in conjunction with advancement in field data management enables a systematic approach in assessing tubular integrity status of wells in near real-time and predicting remaining life of tubulars.

Implementation of this unique, easy-to-use multi-disciplinary application assists in proactive management of integrity, avoids unnecessary workover, and enables cost saving by continued use of existing materials. The application was developed in a computational framework that allows quick integration of physics-based modeling tools for bespoke applications. Furthermore, it supports the development of corrosion monitoring plan, identification of wells with potentially high corrosion, and assists field engineers in defining inspection requirements to maintain well integrity.
Integrating Process Simulation Modeling and Predictive Analytics to Gain Deeper Insights into Machine Health and Performance
Authors: Minocher Homji Ruzbeh , Bhardwaj Akshay
Published: November 2019

The efficacy of machine learning (ML) algorithms for turbomachinery condition monitoring can be compromised by the lack of robust historical data for training. While unsupervised or deep learning (DL) algorithms may be used when sufficient volumes of ‘labeled’ data are unavailable, they offer limited insights into detected anomalies or outliers. Additionally, the inherent dependency on data volume and variety delays the deployment of these algorithms, making an ML-only approach unsuitable for situations such as a machine's first operating run.

The paper discusses how a combination approach utilizing both first-principle based performance algorithms and ML algorithms can address several shortcomings of the ML-only approach. Examples are provided to demonstrate that one type of algorithm can outperform the other in the detection of specific anomalies. Therefore, when deployed in parallel, they provide the ability to predict / detect a larger universe of machine faults. The combination approach can also address the lack of interpretability inherent to ML algorithms in cases wherein both sets of algorithms show anomalous behavior.

To further address the issue of data inadequacy and poor data quality, the concept of simulation-based transfer learning is introduced. A thermodynamic simulation model is used to generate performance data for a multistage, variable composition centrifugal pump. This data is then used to train two deep stateful LSTM neural network models to predict pump discharge pressure. In the first model only simulation data is used for training while for the second model both simulation and historical data are used.

Prediction results from both models are compared with those from a performance algorithm and an LSTM model trained solely on historical data. Test results demonstrate that the LSTM model trained on both simulation and historical data outperforms the other algorithms. This methodology can be applied successfully to accelerate the deployment and enhance the value of deep learning algorithms for machine performance analysis. An additional benefit of training the model on simulated data derived from well proven thermodynamic/aerodynamic principles, is that the insightfulness of performance algorithms may be ‘inherited’ by the deep learning algorithms.
Applying Brain Science to Achieve Organizational Success
Authors: Al Halyan Dr Amal , Al Badi Abeer , Al Hosani Bashayer
Published: November 2019

Decades ago, scientists believed that the adult brain is fully formed and unchanged. However, it was found recently that the brain is adaptive and can change in both forms: physical and functional forms. This phenomenon is called (neuroplasticity). In simple terms, the neurons (i.e. brain cells) can create newer connections (i.e. physical form) and have better performance (functionality); or go the opposite way. Scientists are greatly interested in this re-wiring characteristic because it can help people with brain injuries to have substantial recovery; and very recently to understand how people can be happier, more engaged and productive at work.

Majority of research available is linking neuroplasticity with how to make employees happier and more productive at work. When people work with positive mindset; productivity, engagement, innovation and creativity improve. However, happiness is still misunderstood as a major drive of performance, due to variety of definition of happiness by scholars (Achor, 2012).

Happiness is a positive psychological state that had been found to be related to work performance and engagement. Work engagement is also a positive psychological state defined by feelings of being energetic, empowered, satisfied and being absorbed in the state of being totally engaged at work (Schaufeli, 2012). Engagement had been extensively studied due to its positive outcome on personal and organizational levels; such as: reduce absenteeism, preventing burnout, increase productivity, having less errors and occupational injuries and accidents, innovation and creativity and having better financial results (Burke & Cooper, 2016).

The following article demonstrates a field experiment which was conducted on approximately 50 employees working in a technical support department for the drilling function in ADNOC Onshore, Abu Dhabi, The United Arab Emirates. The activities are a series of ongoing interactive and team building events that started with the beginning of the year 2019; aiming to provide a positive work environment that enhance bonds between team members, creating positive mindset, and encouraging innovation and creativity.
Correlation Between Drilling Parameters and Geomechanical Properties - The Hidden Geomechanical Information
Authors: Lamik-Thonhauser Bouchra , Schoen Juergen H. , Koller Christian S. , Arnaout Arghad M.
Published: November 2019

The drilling process is fundamentally controlled by the interaction of the bit with the rock which is characterized by its mechanical properties. The focus of various studies is directed mainly on the optimal design of drill bits and drilling operations related to the (expected) geological situation for a safe and efficient drilling process.

The question arises: "Is it possible to extract any rock properties information from drilling data?". In a previous paper the correlation of drilling properties with the lithology of penetrated formation was evaluated. A clear correlation could be demonstrated by applying different statistical methods.

Based on these results a simplified model for the rock destruction at the bit is developed and a "formation strength parameter S" is defined. As a cut-force parameter in the equation, weight on bit (WOB) is used primarily for vertical sections. For deviated or horizontal sections the differential pressure Delta-p is a more relevant parameter. A new parameter S is calculated as a function of drilling parameters only (RPM, WOB, Delta-p, Bit-size). This new parameter S is compared with existing parameters for rock characterization (Mechanical Specific Energy) and discussed herein.

For four wells this parameter S is plotted as function of the depth representing a first geomechanical model. The main results are:

Well A: Geomechanical characterization of different clastic and carbonate sections of a vertical well. Clastic (sandstone, shale) and carbonate (limestone, dolomite) are clearly separated. The carbonate section is detailed and subdivided in dense-hard and fissured-porous parts.

Well B: Calculations are made for vertical (based on WOB) and deviated/horizontal section (based on Delta-p) and compared; for the deviated/horizontal section the Delta-p version gives more reliable results.

Well C: For a specific section of this well after drilling a profile of Unconfined Compression Strength (UCS) with a standard well-logging algorithm was calculated. A comparison of the "during-drilling" derived geomechanical model in terms of S and the "post-drilling" derived in terms of UCS demonstrates similar tendencies and confirms the character of S as a geomechanical measure.

Well D: Data (WOB, ROP, RPM) for this example are logged as part of a test of the new PDS Digital Drilling technology (Powerline Drillstring Technology) in an igneous formation (phyllite). It demonstrates the ability to discriminate different geomechanical sections of one formation.
Unique Fit for Purpose Combination of Three Dimensional Cutters Enabled Operators to Reduce Drilling Cost by Improving ROP and Footage Drilled
Authors: Konysbekuly Galymzhan , James Biju , Lomov Alexander , Gumich Dmitrii , Ungaliev Gaukharbek
Published: November 2019

Finding a safe and efficient approach to drilling in challenging applications is a difficult task for drillers because each field is unique. The industry's common ambition is to use various technologies to increase the mechanical penetration rate and reduce overall drilling time. Most recent studies show that drilling bits play an important role in drilling optimization and help to overcome most of the challenges connected with the rock destruction process and tool lifecycle.

In recent years, 3D PDC cutters such as ridge diamond elements (RDE), rolling PDC cutters (RC), and conical diamond elements (CDE) have helped to further improve the drilling efficiency in a majority of applications worldwide.

The PDC bit brazed with unique 3D cutters moved the industry set benchmark performance standards to the next level by improving cutter durability and efficiency in drilling. These cutters, depending on the shape, can improve ROP, durability, and can improve overall cutting efficiency.

Field tests were conducted in multiple applications with multiple customers in RCA and the authors will present several case studies that will document performance improvement in challenging drilling applications. The results clearly show that the combination of this unique 3D cutter has helped operators to bring a step change in performance by improving ROP and footage drilled. In some cases, operators were able to drill the entire section with the bits equipped with 3D cutter combinations where traditionally more than one bit was used to complete the section. Customization of 3D cutters in the appropriate location of the bit is key to this success.
Downhole Temperature Management in Slim ERD Wells
Authors: Ruzhnikov Alexey
Published: November 2019

One of the limiting parameters while drilling deep extended reach (ERD) wells with 6-in. and less open hole diameter is a downhole temperature (DHT). In such small diameters a temperature can easily reach the limit of existing measure while drilling (MWD) and logging while drilling (LWD) tools and restrict the application of them. The manuscript studies main factors affecting DHT in slimehole application and the ways to manage it, as well as field application of obtained results.

The study of DHT while drilling slime ERD wells started with comprehensive analysis of main sources of heat generation, their contribution to DHT as well as temperature transmission along the borehole. The main sources and factors (as geology, well design and profile, BHA and drill string design, drilling fluid type and design, the drilling practices, ROP, friction factors etc.) were ranked by its impact, followed by the development of the model which could simulate their contribution. Based on the model the prevention and mitigation measures were developed to keep DHT within desired limit during a well construction process.

The study was implemented while drilling slime ERD wells in the fields (Middle East) with static reservoir temperature of 250 - 260 deg F. All the modeling results were confirmed with actual field data proving the validity of the simulations. It was confirmed as well that the downhole temperature management in slimehole application is more complex due to many limiting factors, when main of them are coming either from rock properties, like fracture gradient or downhole tools (for example both are limiting the flow rate which found to be the key player in DHT management).

It was shown that even with all developed measures to maintain DHT in slime wells the limit can be reached in deeper wells, due to limits of the downhole tools available in the industry.

The manuscript describes an approach to do the engineering study of one of the main limiting factors which can prevent drilling of deep ERD wells.
Legal Tips and Tricks for Capital Projects
Authors: Robottom Luke , Tarancon Plata Raquel
Published: November 2019

This paper will consider some of the most common causes that result in major capital projects running into difficulties - including time pressure, inadequate planning, scope changes and communication failures – and will discuss potential ways to mitigate the risk, and help reduce the prospect, of future issues arising and how best to address them if they do (inevitably) arise. In particular, this paper will explore possible internal arrangements – including the involvement of the legal function at all stages of a project (from inception through procurement, execution and finalisation) - and contractual mechanisms which can be used to speed up decision making, reduce the length and complexity of negotiations, manage unexpected events and avoid commercial issues escalating into legal disputes.
Challenges in Custody Metering System in Unstabilized Crude
Authors: Devarajan Umakanth , Chandrasekaran Jagadesh , Paul Raju , R. Kamal Faris , Takieddine Oussama
Published: November 2019

The Design, Installation, commissioning and handover of Custody metering system is very very critical for any project completion. This paper addresses major challenges and the corresponding mitigation methodologies in the design of a custody metering system in an unstabilized crude application in recent Buhasser FFD project.

Custody meter is provided for measuring the Oil production from Bu Haseer Production Separator in Zakum plant at Das Island. The Custody meter is fiscal type and designed as a packaged unit. Custody meter package consist of one working, one standby arrangement and one common pipe proving system. The Metering Package includes the following main equipment and instruments: Coriolis flow meters.Pressure and Temperature transmitters.Proving system with double block and bleed valves.Automatic Sampling systemFlow computing systemInlet/Outlet Valves (MOVs)

The Bu Haseer Oil at the outlet of Custody meter is routed to the existing Zakum Inlet oil manifold which is feeding to all existing Separation trains in the Zakum plant.
A Successful Deployment of Level 4 Multilateral Isolation Completion System
Authors: Al Ansari Nawaf , Racine Baidy
Published: November 2019

In the past, accessing laterals after a multipacker completion system installation in a multilateral well presented significant risks to drilling operations because certain crucial operations, such as acid stimulation, required a rig on location.

Recently, a Middle East operator successfully installed an isolated multilateral completion system. The system was deployed in a well located in an onshore field in the Arabian Gulf region.

The isolated multilateral system was customized for multilateral wells that require re-entry capability to access the lateral. The system provided a completion window equipped with landing profiles and sealbores that enable deflector settings for lateral access or isolation sleeves for lateral control. Additionally, a unique latch coupling allowed for installation at the optimum azimuth and depth of the system for lateral re-entry operations.

Historically, in installations that required access to the lateral, a pilot hole had to be drilled and subsequently plugged and abandoned to avoid running a dual-packer completion, followed by running a single packer as an alternative to enable safe stimulation of the lateral. Using the new multilateral isolation system enabled the first combined observation and producer well with a dual-packer completion string.

The well represented a technical milestone for the service company in the development of multiple reservoir fields. Using the isolated multilateral completion system allowed the operator to achieve the following results:

Maintain accessibility to the observation bore for future monitoring and producing from the other laterals. Improve surface infrastructure by reducing the number of wells to be drilled. Save on drilling and completion costs with individual observation wells. Achieve accessibility through the completion on either lateral independently. Perform acid stimulation treatments using a rigless unit at any point during the life of the well through a multipacker completion. Risk reduction with drilling rigs because critical operations, such as acid stimulation and well testing, can be satisfactorily performed using a rigless unit instead of a rig on location.

The identification of further benefits and lessons learned will be addressed in future work.

In conclusion, the Middle East operator had achieved success in the deployment of newly acquired technology for the multilateral/single-bore completion with multipacker systems.
Field Testing an Accurate, Non-Nuclear, Inline Wet Gas Multiphase Meter
Authors: Annamalai Gautham , Rodriguez Daniel , Soto Marcos
Published: November 2019

In today's oil and gas industry, the importance of accurate measurement of wet gas flows has become paramount due to the recent growth in production costs and continuous fluctuation in crude oil prices. Typical wet gas applications have Gas Volume Fraction (GVF) ranging from 95 to 100 percent and hence the accurate measurement of the phase fractions, especially the water fraction at such low liquid flowrate is a serious challenge. Standard multiphase flow meters were found to be inadequate to operate in such conditions. Hence significant effort is taken by several manufacturers into research and development of ‘wet gas’ flow meters which can accurately measure the three-phase flowrates. Taking on the challenge, an inline non-nuclear wet gas metering system was field tested in Argentina to measure the three-phase flow rates under existing field operating conditions and the results were compared to an existing conventional test separator readings to find out if it can serve as a reliable replacement to the expensive test separator.
Mitigating Challenges during Commissioning and Start-Up of Oil and Gas Projects - Effective Risk Allocation through Appropriate Legal Frameworks / Mechanisms
Authors: Lahiri Shourav , Utuk Raymond
Published: November 2019

This paper identifies and analyses ways in which effective contractual approaches can lay the foundation for mitigating various challenges project sponsors and contractors face during the commissioning of oil and gas projects. It achieves this by reference to specific circumstances that, while often arising in contexts outside of commissioning, raise specific challenges in commissioning scenarios. The paper includes a short case study that is referred to where necessary, along with examples of some drafting which go towards addressing the challenges identified. While there is a lot of literature available on the technical and procedural aspects of all phases of commissioning of large projects (including oil and has projects), there is little in the way of content relating to the role that contractual approaches play in ensuring that the various commissioning risk elements are identified and apportioned accordingly among the stakeholders. This is the lacuna that this paper seeks to address.
Cost-Effective Application of Subsea Production System as Field Development Concept in Shallow Water Environment
Authors: Jamaludin Mohamed Ajmel
Published: November 2019

While the first subsea production system was installed in a shallow water environment (West Cameron field in Gulf of Mexico, by Shell in 55ft water depth, 1961), subsea development concept has been more synonymous with deepwater development. It has not been a development concept of choice for shallow water development in Middle East and Asia mainly due to the perception that it has higher life cycle cost and difficult to intervene.

Subsea production concept can be a competitive option vis-à-vis topsides production concept in certain circumstances. More often than not, project economics dictates that development capital expenditure (CAPEX) requires to be as low as practicable; and pre-investment in the initial phase of the project development needs to be carefully managed to minimize its impact on CAPEX and net present value (NPV). Subsea production system are inherently fit-for-purpose and provide an ideal opportunity for project owners to assess the potential of the particular field before deciding to proceed with full-scale development in the subsequent phase.

The fact that there is a large number of shallow-water subsea production systems installed and operated worldwide in the last 30 years provide sufficient track record, lifecycle cost and reliability data that could be used by field development and front end engineers in coming up with a feasible development concept with attractive NPV.

Subsea production system in a shallow water environment is a proven concept predominantly due to the following factors: Provide alternative development option where fixed structures are not cost-effective:a) Where development costs may not justify the CAPEX for a platformb) Where brownfield expansion requires low well counts Optimize drilling program:a) If field reservoir areas are not reachable by deviated drilling from surface wells, producing hydrocarbon from multiple fixed structures might not be economically feasibleb) Subsea completion and production system offer better flexibility in term of field layout and well top-hole positioningAccelerated development cycle:a) Average 15-18 month to first oil from approval of Field Development Plan (FDP)b) Capital Investment is returned in a more timely mannerMinimize cost on extended well testing-Longer well testing operations from a floating vessel with a lower cost are possibleImproved health, safety and environmental (HSE) performance - Removes people from offshore, potential to reduce visual and environmental impact

This paper will demonstrate that subsea development is a matured concept that can be attractive for shallow water applications.
Intervention-Less Unloading Gas Lift Well Completion Design Using Shearable GLVs and Remote Actuated Barrier Device
Authors: Al Khatib Osama , Mason Jane , Beaman Daniel , Wills John , Brodie Alan
Published: November 2019

The Extended Reach Drilling (ERD) field re-development of a giant offshore field in United Arab Emirates (UAE) from four artificial islands predominantly requires the use of artificial lift (gas lift) to assist in unloading the wells post-completion operations and enhance reservoir production recovery rates. The vision was to achieve a well completion that allows for intervention-less unloading via gas lift using shearable Gas Lift Valves (GLV) and Remote Actuated Barrier Devices (RABD). The key principals in developing a solution to achieve this vision were to reduce rig time by avoiding critical path unloading, minimize post-rig activity to install live gas lift valves, and eliminate HSE exposures. Historically producer wells were completed with dummy gas lift valves and a frangible barrier device to facilitate the required completion pressure testing and provide barriers for rigging down from well. Coil Tubing (CT) was used to break the barrier device and kick off the wells with nitrogen. Once gas lift is available, the wells would be shut in, and a series of wireline interventions carried out to replace the dummy valves with live GLVs. This time consuming and costly process increases in cost when subsequent rig location covers the well that needs intervention; critical path rig time has been needed to unload wells with CT, in some cases requiring up to seven (7) rig days. This resulted in increased construction cost of each well and additional HSE exposure associated with the rig-less interventions required.

A method was developed to deploy the upper completion with live, barrier qualified Tubing Pressure Shearable GLV’s (TSGLV) and a RABD, which enables all necessary well-construction integrity tests to be performed, and subsequently convert to a production configuration to allow unloading, gas lift and production of wells. Post-completion, well unloading and gas lift is immediately available without incurring critical path rig time or rig-less interventions.

In this paper, the authors will demonstrate the technology that was developed, the qualification and testing program that was implemented, and final solution that enabled the Company to deliver wells successfully with remotely actuated unloading and production without the need for intervention.
Reservoir Characteristics and Resource Potential of Oil Shale in Sultani Area, Central of Jordan
Authors: Li Ke , Samara Hanin , Wang Xuan , Jaeger Philip , Ganzer Leonhard , Wegner Jonas , Xie Lin
Published: November 2019

Oil shale is the most abundant fossil energy resource discovered in Jordan. The objective of this paper is to investigate reservoir characteristics and evaluate the resource potential of the Sultani oil shale deposit in central Jordan, based on their mineral composition, geochemical characteristics and reservoir microstructures.

The samples used for this study were taken from the outcrop in Sultani deposits, South-East of Al-Karak city adjacent to the desert highway. The collected samples were cleaned and made into powder sample, kerogen sample, thin section sample, and ion beam polishing sample. The powder sample was analyzed by X-Ray Diffraction and Organic Carbon Analyzer to clarify the mineral composition and TOC value. The kerogen samples were tested for evaluate the kerogen type and maturity of organic matter. The thin section and ion beam polishing sample were examined by Optical Microscope and Electron Backscattered Diffraction to observe reservoir microstructures. The Sultani shale is formed by various types of minerals, the majority composition is 67.25% calcite and 18.38% quartz, with little apatite, dolomite, and pyrite. The geochemical test shows that: The Kerogen type is dominated by type II1; the Sultani shale can be burned directly and continuously in the air, due to it contains a large amount of organic matter, TOC average value is 14.82%; the value of equivalent vitrinite reflectance is between 0.55% and 0.67%. The Sultani shale is high-quality source rock but with low maturity. Based on Optical Microscope and EBSD result, the micrite (calcite grain size<0.004mm) constitute Sultani shale. Normally, the reservoir should have extremely low porosity, but there is an amount of foraminifer shell fossil which forms the pore structure. The remarkable thing is that the fossil pore have large pore volume and it is poorly connected to its neighbor, the hydrocarbon reserve in the isolated pores.

The Sultani shale is tight reservoir (large pore volume, but poorly connection) with economically attractive resource potential. However, there will be difficult for exploitation, due to it’s specially pore structure. Acid fracturing is feasible technology to connect the isolated fossil pore, thus significantly increase oil production. The Sultani shale can also be burned directly for power generation and get the lime product at the same time, Surface mining is also feasible exploitation patterns.
Lessons Learnt from the use of a Quantitative Risk Based Approach to Manage SIMOPS Activities
Authors: Ignatius Prashanth , Al Hammadi Saud , Basile Girolamo
Published: November 2019

A number of major process industry accidents have involved SIMOPS. Company conducted construction (modifications) activities inside its own plant during the period from November 2017 to May 2018. The Group Risk Acceptability Criteria Guidelines have been defined by Company for the purpose of providing Senior Management with quantitative information about the risk profile during SIMOPS activities and to help them in taking informed decision about the execution strategy to ensure safe operations.

A DNV-GL Phast based model of the plant has been used to assess the risk level. Using Group Risk guidelines for On-site personnel based on the FN (Frequency – Number of Fatalities) Curve, Company evaluated and compared several SIMOPS options prior to the actual works to identify the optimal manning level and schedule to ensure the overall Group Risk laid in the ALARP region.

The quantitative risk assessment served as a tool to derive the optimal manning levels and shutdown schedule during the SIMOPS activities. The manning levels were controlled through additional administrative measures to ensure its implementation.

Moreover, the overall SIMOPS Risk (FN Curve) for the current activity was compared with the risk undertaken during similar previous activities conducted in 2015 and 2016. After the successful completion of the activities, the Risk Assessment was updated to take into consideration the actual manning and schedule inputs for the Pre-Shutdown and Partial Shutdown phases. The actual overall Group Risk (including Pre and Partial Shutdown) was within the Company Group Risk Acceptability Criteria.

Additionally, valuable Lessons Learned were identified such as purging (with inert gas), rather than just the depressurization of the equipment in the units during Shutdown, can contribute to a significant risk reduction.

This paper presents a novel approach to evaluate SIMOPS risk on personnel using a Group Risk criteria based on FN Curve. This provides an additional re-assurance to stakeholders involved in the activity to take informed decisions based on a quantitative risk analysis rather than a qualitative assessment.