Saudi Aramco Research Articles

Words that Matter: The Power of Effective Communication in Saudi Media and Hr Management

Objective: Effective corporate communications are the foundation on which the goodwill., cooperation and employee motivation are built. The dynamic and complex nature of working environment has interconnected communication and human resources management in a way that would require researchers to further investigate. This study examines the impact of effective communications on human resources management in Saudi Arabia’s Ithra Communications and Partnership Division and Aramco Media Production Division, Saudi Arabia. Theoretical Framework: Considering the knowledge gap, this study utilizes the social network theory of communication. the This study is an extension of an original study conducted at Edo State Broadcasting Services, in Nigeria-Benin City. (Okolie and Ayewumi, 2020). Method: This study was conducted through an online survey for 95 employees working for both media divisions at Ithra and Saudi Aramco at Dhahran City. Results and Discussion: The results reveal that overall, there is a significant relationship between human resource management and effective communication. The study so showed that communication exerts a positive and statistically significant impact on human resource management in the media divisions at Ithra and Saudi Aramco at Dhahran City. Implications of the Research: On the basis of these findings, the study recommends that organizations can attain success through the synergy of communication and human resources management. Originality/Value: The study while a replication study is novel in that it explores the relationships between human resource management and effective communication from a contextual perspective and increases the generalizability of existing research

Technology Focus: EOR Operations (November 2024)

International agreements and national policies on environmental sustainability are changing the outlook for enhanced oil recovery (EOR) globally. These changes are highlighted by both monetary and intellectual commitments by oil companies around the world. Saudi Aramco has pledged $1.5 billion toward sustainable technology. In practice, members of Aramco’s EXPEC Advanced Research Center have collaborated with King Fahd University of Petroleum and Minerals to develop sustainable surfactants for use in high-temperature, high-pressure, and high-salinity carbonate reservoirs. They used no or only green solvents to produce soluble, stable surfactants with the potential for biodegradability. In Colombia, Ecopetrol is committed to reducing CO2 emission by 25% by 2030. As part of its efforts, it has been optimizing polymer injection in Chichimene, a heavy-oil field. By estimating life cycle greenhouse-gas emissions and energy consumption, it was able to show that polymer injection and its associated carbon intensity reduction could prevent the emission of 3,200 tons CO2 equivalent. To comply with the UK’s North Sea Transition Deal, which mandates a 50% reduction in offshore oil and gas emissions by 2030, Ithaca Energy and Energy Research Norway is using life-cycle assessment to guide more efficient heavy-oil recovery. By using low-dose polymer injection, instead of alternatives such as thermal EOR, it was able to increase exergy while also reducing CO2 emissions by 35%. In these studies, we already see the effect of the energy transition as companies turn away from traditionally effective but environmentally burdensome EOR methods such as steam injection and new polymers that show equal, if not greater, effectiveness with a reduced environmental cost. As we move forward with further regulation and innovation, it will be interesting to see how emerging technological developments in polymers, nanofluids, and even artificial intelligence can help producers meet both the economic and environmental criteria to maintain profitable fields. Recommended additional reading at OnePetro: www.onepetro.org. SPE 218653 Coinjection EOR Technology Increases Recovery and Reduces Greenhouse-Gas Emissions by G. Wasylchuk, GERI SPE 218690 Steam Generation Using Renewables Energy—An Integrated Approach for Enhanced Oil Recovery Applications by Mustafa Al Ajmi, Petroleum Development Oman, et al. SPE 218962 Reaching a Million Barrels in an Abu Dhabi Field by Focusing on Operations Efficiency by Masud J. Akhtar, Abu Dhabi National Oil Company, et al.

Oral Histories of Social, Cultural, and Environmental Changes in Saudi Arabia Before and After Saudi Aramco

Saudi Aramco’s influence upon the Kingdom of Saudi Arabia cannot be overstated. After the discovery of oil in 1938, a nationwide metamorphosis began to infiltrate desert communities, sleepy fishing villages, and traditional urban centres ultimately influencing the people and their environments in unimaginable ways. Becoming one of the world’s largest oil producers has meant the loss and/or transformation of traditional ways of life. Shepherds, pearl divers, fishermen, and farmers are today’s business owners, executives, and international leaders. How could the development of a single company influence a country and its populace so dramatically? Besides the financial gains, how were individuals, families, and ecosystems affected? What were some of the personal challenges experienced by Saudi citizens? In this paper, the authors address these questions and others using local Saudi knowledge. In total, 20 female university students who participated in an oral history project interviewed their family members to learn how Saudi Aramco affected them personally, their traditions, landscapes, and society more generally. Excerpts from the interviews are highlighted to expose the nuances experienced by the various research participants.

Study Evaluates Long-Term Corrosion Risk of Load-Bearing, High-Power ESP Cable

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 34898, “Long-Term Corrosion-Risk Evaluation of Load-Bearing, High-Power Electrical Submersible Pump Cable,” by Serko A. Sarian, SPE, Alkhorayef Petroleum, and Hattan Banjar, SPE, and Chidirim Ejim, SPE, Saudi Aramco, et al. The paper has not been peer reviewed. Copyright 2024 Offshore Technology Conference. _ In this study, a fit-for-purpose electrical submersible pump (ESP) load-bearing power cable was deployed inside the production tubing of a sour oil well for an extended period of service. Project economics required the power-cable metallurgy to survive long-term exposure reliably for up to 15% hydrogen sulfide (H2S) and high-salinity production fluids. Laboratory tests simulating varying sour well and extended galvanic corrosion conditions have been performed to determine the adequacy of the selected armor metallurgy in downhole corrosive environments. Introduction In recent years, various types of load-bearing power cable-deployed ESP (CDESP) systems have been introduced, eliminating the need to install or remove a conventional ESP along with the completion and reducing ESP changeover time by more than 80%. More recently, live-well CDESP systems have been developed and tested to eliminate the need for a well-kill operation. The most-critical and costly component of such a system is the load-bearing power cable. The cable has the dual purpose of conveyance and long-term powering-up of the ESP. In a conventional artificial lift operation, the ESP is conveyed using the production tubing with a non-load-bearing power cable strapped to the outside of the tubing. This operation requires a workover rig to remove and reinstall the entire completion and a killed-well operation that might permanently damage the reservoir. The main advantages of a CDESP system include operational efficiency gain and cost reduction, no reservoir skin damage, and production-loss minimization. However, a few challenges exist with the use of CDESP. These cables must have significantly different structures from commercial oil and gas power cables. These differences are detailed in the complete paper. Cable-Design Requirements CDESP system criteria include multiple-year continued service in adverse oilwell and reservoir conditions such as sour fluids, high gas/oil ratios (GOR) and temperatures, and abrasion caused by solids production. The following product acceptance requirements were set in advance: - Three redeployments or retrievals after the initial deployment - Single deployment continued runtime to meet or exceed the regional conventional ESP system runtime Based on regional statistics, a conventional ESP system single-deployment average run time is 2.5 years. The effective CDESP power-cable service life target then becomes 2.5 years × four total deployments = 10 years, which served as the basis for all cable-associated testing and reliability metrics.

Harnessing the sustainable potential of groundwater in Saudi Arabia via remote sensing

Groundwater resources in water-stressed regions, such as the Middle East, face significant challenges due to low precipitation, high temperatures, and elevated evaporation rates, which are compounded by anthropogenic stresses. In this context, Saudi Aramco (the national petroleum and natural gas company of Saudi Arabia) has contributed in the search for potential groundwater sources to ensure an adequate supply of potable water for the country’s citizens, agricultural needs, and industrial usage. In this study, we combined geographic information system (GIS), remote sensing (RS) and analytic hierarchy process (AHP) techniques to evaluate the vulnerability of groundwater potential (taking Hail as a case study). With a total of 7 thematic layers (i.e., geology, slope, lineament density, land use/land cover, annual rainfall, drainage density, and soil texture), we found that groundwater potential zones with moderate to high coverage account for 91.9%, which is notably close to the borehole data, with a groundwater potential validation accuracy of 90.0%. The obtained results offer a crucial tool for decision-makers and managers, enabling them to develop timely protection and monitoring measures for groundwater resources.

Advancing Water Deoiling Efficiency in Petroleum Production: A Comprehensive Case Study of Hybrid Flotation Technology Integration

_ The efficient management of increasing water cuts in oil fields is paramount for sustaining profitability and minimizing environmental impact. This article presents a comprehensive case study conducted by Saudi Aramco, focusing on the integration of hybrid flotation technology into a gravity water/oil separator (WOSEP) to enhance deoiling efficiency and reduce operational costs and carbon emissions. The retrofit involved merging enhanced gravity separation with induced gas flotation (IGF) within the same vessel, resulting in significant improvements in deoiling capacity, outlet oil-in-water content reduction, and operational efficiency. Detailed insights into the design, operation, and performance of hybrid flotation systems are provided, offering valuable guidance for similar initiatives in the petroleum industry. Introduction Petroleum production facilities face escalating challenges with increasing water-production rates during crude-oil extraction, particularly in waterflooding operations for secondary oil recovery. This trend not only escalates operational costs but also intensifies environmental concerns, particularly regarding energy consumption and carbon emissions associated with water-handling processes. In response to these challenges, Saudi Aramco embarked on a pioneering initiative to enhance water-deoiling efficiency by integrating hybrid flotation technology into a conventional gravity WOSEP. This case study presents a comprehensive analysis of the design, implementation, and outcomes of this transformative project, offering valuable insights for the broader petroleum industry. Methodology The upgrade process commenced with an assessment of the existing WOSEP system and its operational challenges. Recognizing the impending capacity constraints and escalating oil-in-water content, Saudi Aramco’s engineering team opted for a holistic approach that combined enhanced gravity separation with IGF within the same vessel. The retrofit involved reconfiguring the internal components of the WOSEP to accommodate the hybrid flotation system, including the installation of advanced plate-pack internals for gravity separation and the integration of IGF cells for additional oil removal. Rigorous testing and optimization procedures were conducted to ensure seamless integration and optimal performance of the hybrid system. Gas/Oil Separation Plant Process Description In a typical gas/oil separation plant, the initial phase involves the extraction of crude oil, associated gas, and produced water from wells via a production manifold. These constituents are then directed to a three-phase separator, also known as a high-pressure production trap (HPPT). In the HPPT, free water droplets are separated from the oil through gravity separation, aided by demulsifier injection at the production header. The separated free water is discharged to a WOSEP, typically a gravity separator, for deoiling.

Study Conducts Mechanical Evaluation of Nonmetallic Tubulars

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 214488, “Mechanical Evaluation and Intervention in Nonmetallic Tubulars Using Current Technologies,” by Mohamed Larbi Zeghlache, SPE, and Khaled Al-Muhammadi, Saudi Aramco, and Iqbal Pervaiz, SPE, Baker Hughes, et al. The paper has not been peer reviewed. _ With increasing interest in nonmetallic products, such as fiberglass tubing, for downhole applications, ensuring well integrity in a similar way as is achieved for standard carbon steel completions is essential. One important aspect of well integrity is the ability to routinely access the downhole condition of the tubing and perform basic interventions. The complete paper demonstrates testing and validation of different mechanical evaluations of the integrity of fiberglass tubing using logging and intervention tools. Introduction Fiber-reinforced polymer composites have been used efficiently for various structural applications, including primary structures for which safety is a major design requirement. Fiber-reinforced laminate is very sensitive to out-of-plane loading, however, because it exhibits relatively low transverse properties. The resulting impact damage in fiber-reinforced polymer composite usually reduces its postimpact mechanical properties. The damage phenomenology in fiber-reinforced polymer composites involves many different mechanisms of degradation. Contrary to metallic materials, fiber-reinforced polymer composites can experience damage evolution followed by a catastrophic failure without prior notice. The inspection and monitoring of such damage during a structure’s lifetime are very challenging. Moreover, classical nondestructive testing techniques are difficult to implement for real-time structural health monitoring (SHM). It is, therefore, important to develop a reliable SHM technique that can both increase safety and reduce operational costs by optimizing inspection and repair. Well-Integrity Evaluation Of common barrier-inspection technologies, cement evaluation using sonic and ultrasonic measurements is very challenging across coated or nonmetallic casing. In the case of nonmetallic pipes such as fiberglass and composite pipes, this measurement is yet to be investigated for proper transducer design and signal processing. Magnetic and electromagnetic technologies cannot be used for casing inspection because the pipe material is an insulator and prevents any current flow. The simplest and most straightforward technologies remaining are mechanical tools for inner wall inspection. For this reason, testing was conducted to evaluate the effectiveness of multifinger caliper (MFC) logging in fiberglass casing and to simulate intervention operation through puncher and cutter services. MFC Log in Steel Casing An MFC is a mechanical tool that provides, through its fingers, high-resolution accurate radial measurements of internal diameter of tubing or casing string. MFCs are used to detect very small changes to the internal surface condition of the tubing or casing with a high degree of accuracy. The tool may be run with extended fingers to increase the measurement range. An MFC tool works in any type of fluid present within the wellbore. MFC detects the scale, wax, or solid buildup on the inner surface of the pipe and any deformation or ovality in the pipe.

Technology Focus: Unconventional and Tight Reservoirs (July 2024)

Unconventional reservoirs bear a unique perplexity in that, at every scale, they are different from their conventional counterparts and even one another. Small nuances in any one parameter can result in a vastly different well result, which may affect how an area, or even an entire play, is interpreted. This month’s selection of papers is all about those differences, in recognition that it is technology that drives innovation through understanding what these differences mean and how best to extract value from these vast resources. Starting at the well scale and looking at the benefits of knowing the efficacy of each stimulation stage, paper URTeC 3864145 is from the Ordos Basin in China. Investigating hydraulic fracture performance on a stage-by-stage basis proves time and time again that understanding the details can improve overall development outcomes. The case study reviews two hydraulic fracture diagnostic techniques used in combination to determine water breakthrough and shutoff plans. Zooming out to the play scale, paper SPE 216292 is focused on the most variable of unconventional reservoirs: the carbonate reservoir. This case study of the Austin Chalk formation in Texas analyses the production uplift from application of horizontal, multistage fracture stimulation technology in tight or fractured carbonate reservoirs. The application of unconventional technology in carbonate reservoirs can extended field life, and the deployment of this technology should be considered for any redevelopment or reassessment of potential resources trapped in tight carbonate reservoirs. Finally, paper OTC 34832 draws on the concept of innovation that is required to unlock unconventional resources. Novel methods of stimulation are the cornerstone of unconventional technology in that well stimulation is a basic requirement of all low-permeability reservoirs. The paper describes a trial pilot from idea through execution from Kuwait Oil Company for enhanced oil recovery in tight formations using downhole hydrogen generation from in-situ exothermic multistage chemical reactions between two unique hydroreacting agents. The paper also provides lessons learned and optimization insights from the trial, concluding that a successful, low-cost alternative stimulation technique was demonstrated and repeatable. Recommended additional reading at OnePetro: www.onepetro.org. SPE 216139 Tight Gas Reservoir Characterization and Comparison of PLT Methods: Microseismic Monitoring, Fiber-Optical Production Logging, and Tracer-Coated Sand Monitoring Applied in the Same Well by Xiao Yao, Petrochina, et al. SPE 216149 New Insight in Developing Tight Fractured Carbonate Reservoirs, Mishrif Formation, West Kuwait by M. El-Jeaan, Kuwait Oil Company, et al. SPE 215712 Successful Utilization of In-Situ Dune Sands in Saudi Arabian Unconventional Frac Operations by Nahar Qahtani, Saudi Aramco, et al.

Adaptive Approach for Reservoir Modeling Reduces Project Time, Improves Collaboration

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper IPTC 23935, “Breaking the Chain: Novel Use of Adaptive Model Approach for Reservoir Modeling Reduces Time Duration of Project and Improves Collaboration,” by Anthony R. Thompson, SPE, and Cesar E. Zerpa Bolivar, SPE, Saudi Aramco. The paper has not been peer reviewed. Copyright 2024 International Petroleum Technology Conference. _ The complete paper details how the reservoir modeling workflow can be accelerated, and uncertainty reduced, even for challenging greenfield prospects by constructing multiple small fit-for-purpose integrated adaptive models instead of one all-encompassing model. This workflow reduces the number of items on the critical path while simultaneously enabling static and dynamic data to be integrated before the static model is finalized. In addition, this approach enables new ideas to be evaluated more rapidly without affecting the critical path of the project. Adaptive Models Adaptive models are constructed to evaluate a single parameter, although this does not preclude an adaptive model being used to answer more than one question simultaneously. Critical to the successful use of adaptive models is the fact that they can be constructed quickly. This enables the various inputs received to be assessed and quality-controlled within the static and dynamic models the moment the input or interpretation becomes available. The construction of adaptive models normally is best achieved through the construction of a workflow in the static modeling package. Initially, the workflow may only consist of the construction of a grid in which to start to place wells. As data become available and are quality-controlled into the model, in most cases, this can be included into the workflow, enabling more constraints to be applied to the subsequent modeling framework. When the adaptive model is being simulated dynamically, it is critical that the model runs quickly. The use of a sector model can be considered for greenfields because the history-matching parameters before production starts are limited to the vicinity of the well. Full-field models are only required when an event occurs across the whole of the reservoir. Adaptive Modular Modeling Process In contrast to the classical approach to reservoir modeling, which uses a chain-type approach, the use of adaptive models brings components together in the sequence of work completion. This means that the various components of the model can be competed when the resource or team member is available. Thus, until very near the end, the project is unlikely to be waiting on the input of one person.

Technology Focus: Completions (April 2024)

To start a text for high-level readers with a cliché is always a risk, but I will take it: “Data is the new oil.” When British mathematician Clive Humby coined this clever sentence in 2006, the thought-provoking idea behind it was that both oil and data need to be refined and processed to have value. Time and repetition eventually shaped the new, more common-sense meaning that data is as valuable as oil. And when the data refers to oil exploration and production, Humby’s statement becomes resounding, especially in its original meaning. The oil and gas industry, notably the completion activity, with its distributed sensors, optical fibers, permanent downhole gauges, sealed-wellbore pressure monitoring (SWPM), and microseismic, has generated a fantastic amount of data, which has increasingly been properly refined and processed, producing more information—and more oil. A quick search of OnePetro shows the number of papers that deal with the use of artificial intelligence with massive amounts of data that are being made available in the cloud to solve everything from the most prosaic completion decisions to the automatic design of stimulations in naturally fractured reservoirs. A good example of the use of data is shown in paper SPE 212922, which provides an in-depth analysis of interventions in the UK sector of the North Sea. Most of the conclusions, although mostly based on the UK Stewardship Survey, can be easily extrapolated to other regions of the world. And one of them puts its finger on the wound: the fear of asset managers of conducting interventions, even though they appear to be highly effective and economically viable. Paper SPE 212367 discusses the automation of SWPM data analysis for automatic volume-to-first-response matching, a great evolution in the design of refractures in the legendary Eagle Ford shales. And, if the evolution of completing unconventionals led the US to its historic production record in 2023, with more than 16 million BOE/D, in Argentina, shale gas has been a driver of development. The evolution of completions in the most famous unconventional prospect, Vaca Muerta, can be followed in paper SPE 212574. All of these great readings prove the cliché that “data is the new oil.” To complement the reading, a paper that will bring a discreet smile to a generation that breathlessly watched spaceships and even planets being destroyed by lasers, paper SPE 215016, details the industrial use of lasers in perforation. The future has finally arrived. To close the selections, two papers present current and important topics: completion options for carbon capture, use, and storage (SPE 216187) and innovations in autonomous inflow control devices, with the ingenious activation of the apparatus with chemical devices (SPE 216041). Recommended additional reading at OnePetro: www.onepetro.org. SPE 215016 First Industrial High-Power Laser Perforation Deployment by Sameeh I. Batarseh, Saudi Aramco, et al. SPE 216187 Improving Injection Efficiency in CCUS Wells: A Comparative Analysis of Different Completion Designs by Prakasa Bona, Halliburton, et al. SPE 216041Configurable Adaptive Chemical Inflow Control Device Eliminates Intervention by P. Asthana, Saudi Aramco, et al.

Technology Focus: Artificial Lift (March 2024)

The industry is now in its second year beyond the COVID-19 pandemic, and the workforce has changed in many ways, but issues facing production performance remain. Major conferences saw 116 submissions from 28 countries, with 64% regarding electrical submersible pumps (ESPs), and 18% and 8% devoted to gas lift and rod lift, respectively. Many of the papers dealt with case history successes. That is all well and good, but it doesn’t necessarily drive reader interest if it can’t be applied to their asset. The top three papers were selected on the guidelines of clarity of the abstract in addressing the scope, methods/procedures/process, results/observations/conclusions, and novel or additive information. The papers described here focus on novel unconventional horizontal downhole pump card signatures, carbon reduction through alternative energy to pump wells, and predicting downhole-discharge pressure of ESPs. Paper SPE 214723 presents a discussion of the design, evaluation, and field testing of a new type of mechanical gas separator with what the authors term a “hydrohelical” design. The separator, in Permian Basin tests, almost doubled the flow capacity of conventional gas separators with a high level of efficiency. The authors draw particular attention to the improvement of ESP operations under multiphase conditions. Carbon reduction is a hot topic, and paper OTC 32671 does not disappoint as it looks at the use of a 10-MW floating solar photovoltaic power system to meet the energy needed for 10 ESP wells on an oil platform in the Brazil equatorial region. Collaboration with the National Renewable Energy Laboratory and its System Advisor Model was used with extensive meteorological and wind data to examine the sustainability of green energy use for the petroleum industry and offer valuable guidance for future renewable energy projects in regions with similar characteristics. Finally, paper SPE 216598 comes from Sudan and Saudia Arabia and focuses on digital solutions for the challenge of knowing the downhole-discharge pressure of an ESP system. Most ESP systems do not have downhole gauges, so an artificial neural network (ANN) approach is used to predict the ESP discharge pressure for performance optimization. Forty wells and more than 12,000 data points were reduced to 16 inputs plus one hidden layer of seven neurons to provide a high degree of accuracy in prediction of discharge pressure. The authors state that the ability to accurately predict discharge pressure can lead to the early detection of possible anomalies, which can prevent costly failures and reduce downtime. Artificial intelligence technology may improve the accuracy of ANNs, but, for now, ANNs are worth a look to obtain much-needed ESP discharge pressure. Other notable papers dealt with gas separation, ESP reliability, and the increasing challenges of low rates, low pressures, and high gas fractions. Recommended additional reading at OnePetro: www.onepetro.org. SPE 214913 Solved: ESP Shutdowns and Restart Issues—Novel Pump Protection and Active 3D Dispersion System Improve ESP Performance in Multiple Wells by A. Bhattacharjee, SLB, et al. SPE 215474 A New Artificial Lift Approach in Telisa Low-Productivity Reservoir: Utilized Very Low-Rate ESP by Agus Aryanto, Medco E&P Indonesia, et al. SPE 215170 A Comprehensive Study of a Novel Submersible Pump by Hattan Banjar, Saudi Aramco, et al. SPE 214722 Case Study: Predicting Electrical Submersible Pump Failures Using Artificial Intelligence and Physics-Based Hybrid Models by Shejuti Silvia, Baker Hughes, et al. SPE 214733 Gas-Flow-Management Technology Designed To Decrease Downtime and Improve ESP Efficiency by S. Fulwider, ConocoPhillips, et al.

Enzyme-Based Cleanup Fluid Effective for High-Temperature Filter-Cake Removal

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 214628, “Enzyme-Based Cleanup Fluid for High-Temperature Filter-Cake-Removal Applications,” by Ali A. Al-Taq, SPE, Hussain A. Al-Ibrahim, SPE, and Ali A. Alsalem, SPE, Saudi Aramco, et al. The paper has not been peer reviewed. _ Enzyme-based cleanup fluids are preferred for filter-cake-removal applications, especially in horizontal wells, because of several advantages compared with conventional cleanup fluids, including low reactivity, less corrosivity, more-positive environmental impact, and, ultimately, homogeneous filter-cake-removal coverage. Most enzyme-based cleanup fluids are limited to low temperatures. In the complete paper, the authors describe extensive laboratory work conducted to evaluate an enzyme-based/in-situ generated organic acid cleanup fluid for a water-based mud at a temperature of 250°F. Experimental Work Before describing their experimental methods, the authors provide a literature review in the complete paper detailing cleanup or removal of filter-cake damage, natural cleanup, acids and oxidizers, enzymes, enzyme-breaker systems, and factors influencing performance of enzyme breakers. The drill-in fluids used to perform the high-pressure/high-temperature (HP/HT) filter press tests were laboratory and field samples. The field samples were obtained from Well A. XC-polymer, starch, and PAC-L polymers were used in the drilling-fluid formulation to control fluid loss and to increase its viscosity. Potassium hydroxide was added to adjust the pH of the drilling fluid. Potassium chloride (KCl) was used to mitigate fines migration and clay swelling. Fine and medium calcium carbonate particles were used as weighting materials. Equipment used in the experiments included HP/HT filter-press cells, see-through cells, and a pendant-drop instrument. The inductively coupled plasma (ICP) technique was used to measure the concentration of calcium in the spent acid samples. Filter-cake solids before and after the reaction took place were analyzed using X-ray diffraction (XRD) and X-ray fluorescence (XRF) techniques. The concentrations of spent acid samples were measured by acid/base titration using 0.5-M sodium hydroxide solution and phenolphthalein solution as an indicator. Iodine tests were conducted on the treated filter-cake solids to examine the presence of starch. The pH and density were measured for various solutions. Coreflood experiments were conducted on sandstone core plugs. The coreflood-test procedure is provided in the complete paper.

Autonomous Drilling Approach Uses Rotary Steerable System in Middle East Wells

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper IPTC 22975, “Novel Approach to Autonomous Drilling Using Rotary Steerable System in Middle Eastern Oil and Gas Wells,” by Victor Oliveira, Saudi Aramco, and Mohammed Elsadig and Ayman Al-Ghazzawi, SPE, SLB, et al. The paper has not been peer reviewed. Copyright 2023 International Petroleum Technology Conference. Reproduced by permission. _ An operator focused on evaluating and validating a novel approach from its major directional-drilling-service provider using the autocurve-drilling mode to drill curved sections automatically without human intervention. The autonomous curve-drilling technology helped minimize human error, enhance accuracy of well positioning, and improve hole quality for drilling and workover operations. Autocurve-Drilling System Rotary-steerable-system (RSS) intelligence has been improving since its introduction. Around 1990, when the RSS method was introduced, communication with RSS tools was only one-way; downlink commands were sent through flow variations, and the response was monitored. For corrections, human intervention was required by sending new downlink commands. Between 2003 and 2013, downhole automation design and analysis for RSS began with the introduction of closed-loop features in which either verticality or target inclination and azimuth in tangent sections can be maintained. The technology evolved to closed-loop responses in these vertical or tangent modes to adjust the trajectory automatically to the target directions within 0.5° in inclination and 2° in azimuth. The next step for automating the downhole trajectory control of RSS was to close-loop the curve section. This once took increased levels of focus from directional drillers to ensure that they continued reviewing directional responses of the RSS in different intervals to update steering requirements, the steering ratio, and toolface commands. This was a good driver for further improvement of RSS intelligence and updates to desired steering-requirement capabilities to automate curve-section directional control. An autocurve autonomous downhole-automation-control system was developed to address the need to automate curved-section directional control. The intelligent algorithm was developed to change the communication process from including surface intervention to use of only a downhole closed-loop system once directional requirements were established. The system moved away from toolface and steering-ratio downlinking commands to dogleg and toolface commands. As a result, the RSS is no longer dependent on surface intervention for steering requirements but adapts to deliver required dogleg-severity (DLS) commands. This process solved the need for surface dependency. Upon acquiring this information, the tool uses the latest-known inclination and azimuth, and programmed rate of penetration, to create pseudochanges in direction and inclination to follow and automatically calculates a steering ratio to follow the required path. This closed-loop design is performed on a continuous basis within 1 second compared with the average 20-minute process cycle that was used conventionally. Furthermore, the design minimizes the command-downlink requirements to the tool, which further enables the automation path.

CO2 Injectivity Test Proves Concept of CCUS Field Development

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 216673, “CO2 Injectivity Test Proves the Concept of CCUS Field Development,” by Yermek Kaipov, SPE, and Bertrand Theuveny, SLB, and Ajay Maurya, Saudi Aramco, et al. The paper has not been peer reviewed. _ The complete paper presents a unique case study on injectivity tests done in Saudi Arabia to prove the concept of carbon capture, use, and storage (CCUS) capability. It describes the design of surface and downhole testing systems, lessons learned, and recommendations. The injectivity tests were effective in identifying and confirming the best reservoir for CO2 injection and defining the best completion strategy. Creating injection conditions close to CCUS is vital, especially in heterogeneous carbonate reservoirs where the petrophysical correlations for the reservoir model require calibration with dynamic data. Introduction The energy company has conducted an extensive evaluation campaign by drilling appraisal wells through multizone saline aquifer reservoirs on different sites close to potential sources of CO2 at the surface. The evaluation program included coring, openhole logging, formation testing for stress-test and water sampling, and injectivity testing in the cased hole. Apart from reservoir characterization, different completion strategies were evaluated by performing injectivity tests in both vertical and horizontal wells. The lower completion was represented by perforated casing and an open hole. Injectivity Testing Injection tests are a commonly used method in waterflood projects to evaluate the injectivity capacity of the well and reservoir. The test involves an injection period with one or more injection rates, followed by a falloff period (Fig. 1). During the injection period, the liquid is injected at a stable rate to reduce the risk of near-wellbore formation damage caused by fluid incompatibility or exceeding the fracture gradient and inducing formation fracturing. The bottomhole-pressure data acquired during the test is analyzed using the pressure transient analysis method to estimate the permeability thickness, skin factor, and lateral heterogeneities. Additionally, the injection logging profile can be conducted along the sandface to assess completion efficiency and formation heterogeneity. By interpreting the results of the injection test, engineers can optimize the injection rate and improve the performance of the well and reservoir, ultimately leading to more-efficient oil recovery. Injectivity Test: Case Study The injectivity tests were conducted on virgin reservoirs using vertical appraisal wells that were sidetracked horizontally into the reservoirs with the greatest potential for storage. The reservoirs’ depths varied from 4,000 to 8,000 ft, with a normal gradient of reservoir pressure and temperature. The injectivity test design used reservoir properties estimated from the openhole evaluation, such as porosity, permeability, reservoir pressure, temperature, reservoir fluid sample, and fracture gradient. These data were used to set injectivity-test objectives, calculate expected well parameters, select equipment, and plan operations. The primary goal of the tests was to assess reservoir injectivity by injecting water, nitrogen, and CO2 to prove the concept for a CO2-injection project. While water and nitrogen injections are well-known in the industry, the CO2 injectivity test was new and required more attention during the design phase to evaluate all possible risks.

Technology Focus: Well Testing (February 2024)

Standing alone as the shortest month of the year, February also features JPT’s Well Testing Technology Focus, reviewing the latest industry publications on the subject. Well testing has enjoyed a recent uptick in activity and interest as operators continually realize the value in understanding and monitoring the dynamic performance of their reservoirs. Whether it pertains to the deliverability of conventional oil and gas or the storage potential for carbon capture and storage, large-scale dynamic data remains one of the more coveted pieces to the subsurface puzzle. There is no silver bullet for reservoir characterization. Instead, proper characterization will always be the result of integrating static and dynamic data, collected at varying scales, with a macro geological understanding. Technology facilitates the collection of the aforementioned data. With the latest technologies pushing limits of what can be achieved, subsurface engineers must rigorously evaluate what reservoir characterization techniques and tools are suited for project objectives. Formation testing (FT) platforms provide many options for operators to get a first look at dynamic reservoir performance and nearly always precede a well test. After digesting the alphabet soup of acronyms, so many FT options exist that one may encounter what psychologists refer to as “choice overload.” FT objectives also may begin to overlap with objectives traditionally reserved for drillstem tests (DSTs), narrowing a long-standing technology gap. The current advances in FT tools are exciting, and using FT tools to perform a “mini-DST” makes for brilliant marketing. However, “mini” could mean up to 10,000 times less produced volume, which undoubtedly affects objectives thought to overlap. Subsurface complexity is mitigated by defining clear objectives and executing data-collection programs to reduce uncertainty. Caution should be taken in selecting how to dynamically test your reservoirs. Regardless of how advanced hardware becomes, achievable objectives always will be dependent on key factors such as rock and fluid properties, reservoir geometry, and local regulatory and environmental considerations. This month’s papers highlight ongoing developments from different segments of the well-testing discipline. Dive into valuable lessons learned from a frontier carbon capture, use, and storage project, backed by an impressively sized data set and an in‑depth review of multiphase effects. This case study covers differing saturations around the wellbore region and fluid types in operations and should have global applications. Learn about the limitations and potential pitfalls of nonisothermal effects in pressure transient analysis, which pose challenges in the reservoir characterization of geothermal wells. Sensitivities to thermal effects on reservoir rock properties provide intriguing insights. Completion efficiency also may be affected by thermal effects, resulting in additional pressure drop at sandface. Finally, catch up on one of the weapons most recently added to the well-testing arsenal with powerful new FT tools that feature industry improvements for greater flexibility and improved data reliability. Recommended additional reading at OnePetro: www.onepetro.org. OTC 32610 Multiphase Flowmeter Comparison in a Complex Field by Mohammed Alqahtani, Saudi Aramco, et al. IPTC 23050 Frequently Asked Questions in the Interval Pressure Transient Test and What Is Next With Deep Transient Test by Saifon Daungkaew, SLB, et al.

Will the US lead the energy transition? decarbonization policy of American oil companies

The article assesses the chances of the US that recently recovered its former status of a major energy power to become the leader of the energy transition from fossil fuels to the renewable sources of energy. The authors study the key drivers of the oil and gas sector decarbonization within the framework of the fourth energy transition, such as government policy, greening of financial institutions, etc. The article analyzes decarbonization strategies and goals of the main players in the American and European oil and gas markets. The key objectives of the decarbonization process in the US are determined proceeding from the assumption that the country makes a bet on the long-term future of the global oil and gas sector and simultaneously intends to achieve net zero goals by 2050. The authors study methods (such as carbon capture, utilization and storage, direct air capture, broader use of hydrogen, reduction of gas flaring, etc.) and compare results of decarbonization carried out by the US (ExxonMobil, Chevron, ConocoPhillips, Occidental Petroleum) and European (Shell, Total, BP, Equinor) majors, as well as two key oil and gas companies in the Middle East: Saudi Aramco and ADNOC. The conclusion is made that currently the US oil and gas companies lag behind their European competitors in the energy transition sphere, and at the same time the main Middle Eastern players that employ similar approaches to reducing their carbon footprint are gradually catching up with them.

Implementation of Saudi Aramco's SDGS to Preserve the Environment in Meeting Global Energy Needs

The Sustainable Development Goals (SDGs) have become a key guide for global organisations to preserve the environment while meeting global energy needs. Saudi Aramco, one of the world's largest oil producers, has a key role in achieving these goals. This study aims to analyse the implementation of Sustainable Development Goals by Saudi Aramco in preserving the environment in line with their efforts to meet global energy needs. The method that will be used in research is a qualitative research method involving case studies to explain variables related to Saudi Aramco Companies in implementing Sustainable Development Goals (SDGs) to preserve the environment. This research explores various concrete steps that have been taken by Saudi Aramco in integrating the principles of SDGs in their operations. The main focus is on the company's efforts to reduce the environmental impact of its oil production activities, including the reduction of greenhouse gas emissions, water management, and biodiversity protection. The results show that Saudi Aramco has taken various important initiatives in support of the SDGs. They have invested in environmentally friendly technologies, such as increased energy efficiency and improvements in carbon capture technology. In addition, the company has prioritized sustainable water management and efforts to preserve natural ecosystems in the areas where it operates. The research also highlights the challenges faced by Saudi Aramco in implementing the SDGs, including regulatory issues, required investments, and corporate culture change. However, the steps taken by these companies demonstrate their commitment to achieving the SDGs.

Corporate Sustainability and Vision 2030: Exploring ARAMCO's Role in Promoting Social Responsibility for Sustainability

Abstract: Saudi Arabia stands as a rapidly growing economic power. It has emerged as a leading country in adopting and integrating Corporate Social Responsibility (CSR) activities. The aim of the organisation is to be globally preeminent unified energy and chemicals company, functioning in a safe, sustainable and reliable manner. Corporate entity openness and moral behaviour is the focus of Aramco's CSR guidelines. Aramco's CSR principles include achieving long-term progress and adhering to local and international laws. The CSR strategy is imbibed into the company's business strategy, which is founded on four focus areas of sustainable development: Climate change and the energy transition, safe operations and people development, minimizing environmental impact and growing societal value. Each of these focus areas support Aramco’s strategic themes, and align with both Saudi Arabia’s Vision 2030 and the U.N. Sustainable to create a vibrant civilization, flourishing economy and building a determined nation. Method: This study examines Saudi Aramco's on the CSR front, the industry's largest oil exporter. Efforts have been made through the use of secondary data to capture the drivers and modus operandum used by the organization for its commitment towards sustainability. Results: The industry’s largest oil exporter has adopted several practices in their efforts to become socially responsible and sustainable. Evidence (Aramco sustainability report 2022) has revealed that shift in perspective has taken place over the past year, increasing acceptance of the fact that there needs to be a better balance between maintaining energy security, energy affordability, and environmental sustainability. CSR practices have a positive impact on company performance, reputation, customer satisfaction, loyalty, employee engagement and minimizing any negative environmental and social impacts, to build something that will last a company that will still be standing strong, generations from now. Conclusion: The journey towards effective CSR implementation is dynamic, marked by achievements and challenges. Aramco's commitment to CSR, underscored by its alignment with Saudi Arabia's ambitious vision, paints a compelling picture of sustainable growth and impact for the organization and the broader nation. As the landscape of corporate responsibility continues to evolve, organizations that adeptly navigate these waters are poised to contribute meaningfully to both their own success and the betterment of society at large.

Stochastic Economic Ranking Addresses Risk and Uncertainty for Decision-Makers

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 213385, “Stochastic Economic Ranking: A Prudent Way To Address Risk and Uncertainty for Decision-Makers,” by Mahesh Narayanan, SPE, Mehaboob Abdulazeez, SPE, and Khadija Bukhamsin, SPE, Saudi Aramco, et al. The paper has not been peer reviewed. _ Project screening and ranking is inevitable even when an organization faces no resource bottlenecks. In project economic predictions, the stochastic approach is prevalent and proves to be the most natural approach to address technical and commercial uncertainties. In contrast with a deterministic approach, a stochastic Monte Carlo simulation helps in understanding the range of possible outcomes to enable effective decision-making. The objective of the complete paper is to present an integrated stochastic work flow that addresses the subsurface, surface, and cost uncertainties to screen, rank, and grade opportunities early in the derisking process. Introduction The proposed work flow simultaneously can address all technical and commercial uncertainties with a Monte Carlo model and predict a range of possible economic outcomes with customized economic analysis tools. In other words, it can achieve complete unbiased sample randomness in expected project outcomes. The work flow also creates a stage-gate decision-tree approach and reviews economics as a series of staged investments. This helps to expose incremental capital in the life cycle of a project responsibly and help with course correction where necessary. Value Addition: Stochastic Approach A common practice in the oil and gas industry is to simply examine low, middle, and high cases. This is a limited view of possible scenarios and provides a false sense of precision regarding expected project outcomes. The term “stochastic” refers to the property of being well-described by a random probability distribution. A stochastic approach features the following advantages: - A stochastic model addresses uncertainties in inputs with complete unbiased randomness in the outcomes. - By running thousands of calculations and using many different estimates of future economic conditions, stochastic models predict a range of possible future investment results, showing the potential upside and downside of each. - Once the work flow is followed and the model is set up, multiple realizations can be created with a single click. Proposed Integrated Stochastic Methodology In the world of project economics, classical stochastic economics is a tool to address uncertainty and risk. In simple terms, a mean or deterministic view of a production profile, along with one view of a schedule, is taken and blended with probabilistic distribution of cost inputs. This data is then taken through a Monte Carlo model to create multiple scenarios to predict a range of possible economic outcomes. This narrow range of economic outcomes only covers the uncertainty in cost but does not cover variability in well performance and time.

Nanomembrane Approach Reuses Waste, Cleans Produced Water

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 213946, “Nanomembranes From Polymeric Waste for Produced-Water Treatment,” by Anton Manakhov, Iaroslav Rybkin, and Fahd I. AlGhunaimi, Saudi Aramco, et al. The paper has not been peer reviewed. _ In the oil and gas sector, produced water is the most significant waste stream. Among the different materials used for water filtration, including ceramics, polymers, and carbon nanomaterials, polymeric nanofibers can be considered a unique solution that can be used as a membrane or an adsorbent. In the complete paper, the authors write that polymeric nanofibers can be prepared from polystyrene waste. Introduction The management of polystyrene trash and recycling creates a significant environmental problem. While most of this substance ends up in landfills, only a small portion of polystyrene is recycled or burned. By turning this trash into products with added value, recycling will become more appealing economically and will result in lower CO2 emissions and less chemical waste dumped on the ground. At the same time, the use of modified nanofiltration membranes for generated-water purification has been a subject of study for many researchers. The complete paper includes a review of the literature dedicated to advances in this approach. Dissolved polystyrene waste can be used as a feedstock in the electrospinning process to create nanofibrous membranes. Electrospinning is one of the more basic methods for producing nanofibers with dimensions ranging from micrometers to nanometers. Strong electrostatic forces are used to overcome the surface tension of a polymer solution or melt. These pressures produce the ejection of charged polymer jets, which dry as they approach a grounded electrode, where they are gathered as nanofibers. In this work, the nanofibrous polystyrene membranes were prepared from discarded expanded polystyrene waste. Initially, polystyrene waste was collected and dissolved in an organic solvent; then, the nanofibrous membranes were prepared by the electrospinning of nanofibers from this solution. The morphology, pore sizes, and other parameters were controlled and optimized by tuning the concentration of polystyrene, the nature of the solvent, and the spinning voltage to form uniformly sized nanofibrous membranes.