bluuebunny/crossref_metadata_2025_split huggingface dataset:
Machine Learning for Prediction of CO2 Foam Flooding Performance
Authors: Khan Mohammad Rasheed , Kalam Shams , Abu-khamsin Sidqi A. , Asad Abdul 
Published: October 2022

Abstract
In a move towards development of sustainable and efficient hydrocarbon production, the industry looks forward to the deployment of carbon neutral and even carbon negative solutions. Accordingly, CO2 EOR is a viable option to improve recovery and has been applied in mature fields for over four decades. The downsides of poor sweep efficiency linked to viscous fingering and gravity segregation can be sorted through generation of CO2 foams in the reservoir. This work proposes the utilization of machine learning techniques, to predict foam flood performance which will thereby aid in optimization of laboratory core-flood experiments.
This work is based upon consumption of large set of existing laboratory data collected from literature, amounting to more than 200 data points. The dataset reports core oil recovery factor as a function of three reservoir parameters including porosity, permeability, initial oil saturation. While injected foam volume and total pore volume are also considered. Furthermore, the data records contain experiments for various foaming agent types which are catered for during the machine learning model development through the implementation of numerical tags. The input data is then divided in training subset for development of XGBoost model, complemented by integration of exhaustive grid search and k-fold cross validation techniques. Subsequently, the testing subset is reserved to measure efficacy of the developed model. The model development process involves tuning of machine learning algorithm hyperparameters which control the resultant accuracy, while at the same time it is ensured that the issue of model overfitting is avoided. Testing of the established model is carried out through an array of statistical measures including the R2 and RMSE values.
The proposed model is compared with actual experimental data. The machine learning model can achieve high accuracy in predictive mode for the output parameters. Through statistical error analysis performance measurement, it is observed that the machine learning model can predict CO2 foam flood performance with high R2 of around 0.99 and low errors. The excellent accuracy of the XGBoost model is credited to the complex processing involved with intelligent algorithms that can discover underlying relationships among the input variables.
Encouraging Chemical EOR Field Results: First Multi-Well ASP Flooding Pilot Project in a Carbonate Reservoir Worldwide
Authors: Al-Murayri Mohammed Taha , Sulaiman Dawood S. , Hassan Abrahim Abdelgadir , Al-Ajmi Naser A. , Thery Bastien , Maillon Remi , Nesbit Jimmy , Pitts Malcolm John , Dean Elio , Skeans Elii , Dean Robert Matthew , Britton Chris James 
Published: October 2022

Abstract
Alkaline-Surfactant-Polymer Flooding (ASP) has the potential to unlock massive oil reserves in quest of production sustenance within the bounds of profitable economics. Field results from a successful ASP pilot targeting the massive Sabriyah Mauddud (SAMA) reservoir in Kuwait, using a regular five-spot with five acre-spacing are encouraging. Oil cut post softened water pre-flushing reached 0% and tracer data indicated pre-mature breakthrough at the central producer. This necessitated in-depth conformance gel treatment1-3 to induce flow under matrix conditions and softened water injection resumed thereafter for a period of ~3 months, during which oil cut ranged between 2 to 6%. Oil cut then decreased to 0% again, beyond which polymer pre-flushing was introduced for a period of ~2 months, during which oil cut was increased to up to ~4%. ASP flooding resulted in an unambiguous and sustainable increase in oil cut with an average of ~12% over a period of more than 6 months. Furthermore, daily oil production rate after ASP flooding more than doubled. Effective oil-water separation of produced emulsion has been established and maintained using fit-for-purpose pre-heating, chemical dosing and gravity segregation technologies, thus resulting in relatively low BS&W levels in separated oil (i.e., &lt;5%). Potential in-situ scale risks were effectively managed by injection an innovative scale inhibition package composed of inhibited glacial acetic acid in conjunction with a phosphonate-polymeric scale inhibitor into the capillary tubing string of the central producer, during which 100% production uptime was achieved for several months3. Field data demonstrated that in-situ scale risks due to ASP injection were originally overstated because scale issues were limited even without injecting the adopted scale inhibition package. ASP reservoir simulation forecasts indicate that oil rates and oil cut should continue to increase. ASP flooding is ongoing to date and continues to generate important operational learnings and priceless field data to evaluate the techno-economic viability of phased ASP flooding commercial development.
Coupling of a Reservoir Simulator with Geochemistry for Chemical Enhanced Oil Recovery
Authors: Limaluka Angelo Kennedy Lino , Elakneswaran Yogarajah 
Published: October 2022

AbstractChemical enhanced oil recovery (CEOR) techniques are some of the most effective and economical tertiary oil extraction processes. As a key tool for the recovery performance evaluation, reservoir simulation plays an instrumental role in the expansion of the field application of CEOR. However, their framework models essentially the physical aspect of the recovery process. The significant influence of geochemical interactions on the recovery performance remains largely unintegrated. In this study, MATLAB Reservoir Simulation Toolbox (MRST) was coupled with PHREEQC for improved modeling and simulation of polymer flooding and low salinity water flooding (LSWF). The MRST’s polymer model was extended for multi-phase chemical transport by the addition of chemical species in wells boundary conditions, and phase relative permeabilities were modified to account for the wettability alteration effect of the flooding process. In validation, the coupled model showed a good match against PHREEQC in a simulation of a single-phase carbonate core low salinity water flooding (LSWF). It also validated well in the case of matching high salinity experimental results. A demonstrative application of the coupled model in the simulation of LSWF showed 27% maximum incremental oil recovery with a 3.3 mean water-oil ratio (WOR). Furthermore, combining LSWF with polymer flooding achieved the same recovery potential but with much lower water production (0.2 WOR) and doubled production period. These results preliminarily indicate that polymer flooding and LSWF could be combined for at least 27% additional original oil in place (OOIP) recovery with no more than 1 WOR in carbonate reservoirs. However, as this recovery performance evaluation was done in 1D, further work on the coupled model includes improving it for multi-dimensional application.
An Enhanced Integrated Asset Model for Offshore Field Development Strategy
Authors: Azzarone Eleonora , Rossi Roberto , Cirillo Giovanni , Micheletti Giacomo 
Published: October 2022

AbstractThe derivation of an optimised field development strategy is one of the most important tasks in the oil and gas industry. Modern workflows apply complex integrated asset models (IAM) where reservoir and production network simulators are coupled to provide a single model of the entire asset. In this paper we present the solutions adopted to build an IAM for an asset in the current producing scenario, but also modelling future incremental surface facilities’ upgrades, tasks found to be beyond the capabilities of current commercial IAM products.The asset consists of a number of oil and gas fields producing into a common network. A variable gas offtake through existing and future facilities is expected in the field development. Commercial IAM solutions cannot model this or update the constraint on the total production based on the changing offtake volumes. These limitations have been solved by a set of custom scripts embedded in the simulators. The scripts manage the inline separator efficiency both in the current scenario and also when a volume of the produced gas will be sent to the LNG plant planned in the asset future development.The two configurations, i.e., the current producing scenario and the future development one, are based on the same set of reservoir models with different network schemes and facilities’ constraints. The integration of the reservoir and the network enables the determination of the impact of the facilities’ upgrades, namely the installation of a process unit close to the oil production platform and the routing of a fraction of the gas to feed an LNG plant under construction. The total production is increased because of the reduction of the backpressure due to the new location of the process unit and the reduction of the gas flowing to the current treatment terminal. The average gain both in the oil and gas production rates is around 20% for 5 years. Moreover, due to the unique flexibility of the IAM solution, additional projects (such as further developments to the existing producing reservoirs or tie-in of other fields already discovered) can be easily added to the model to simulate the future asset production.For the particular asset being studied, a solution to the challenging reservoir-network coupling issue was developed employing a set of simulation scripts (including Python ones) that enable the modelling of the network configuration in a rigorous way. This approach overcame the current commercial application limitations and expanded the functionalities of each simulator included in the IAM.
Smart Nano Clay to Reduce Water-Based Mud Filter Cake
Authors: Abdul Latif Ummi Alia , Khairul Ikhwan Chong Zuhayra Nasrin Chong , Belhaj Hadi , Al Hameli Fatima 
Published: October 2022

Abstract
Encountering mud cake is a natural consequence of the drilling operation in oil and gas wells. Thick mud cake requires extra drilling efforts to remove it. Thick cake increases filter loss, reduces wellbore space and causes the drill pipe to be prone to get stuck. This study aims at enhancing the performance of the water-based bentonite by using drilling mud hydrophilic, smart nano clay to modify the rheological properties and reduce the thickness of the mud cake. Hydrophilic, smart nano clay is used to enhance water-based mud performance. The content of the bentonite is varied between 2% to 8% by weight of water and the temperature is varied between 25°C to 85°C. The nano clay particle size is increased by 1% starting from 12 to 20 nm in order to modify the rheological properties and, hence reduce the cake. The samples are hydrated, and their pH is adjusted. Viscometer FANN 35SA is used to measure the rheological properties of all samples under standard conditions. The thickness of the cake is measured using MITUTOYO Vernier Caliper. As a matter of fact, by using the nanoparticle water-based mud, it can reduce the mud cake thickness by approximately 56.25%. However, the filtrate volume surprisingly increased by 89% as compared to the collected volume with ordinary clay, determinant coefficients for the base fluid and nanofluid were found at 87% and 96%, respectively, which are close to the best-fitted lines. The average base fluid and nanofluid were found at 0.23657 and 0.12225 inches, respectively. The standard deviation of the base fluid is 0.08229, indicating that approximately 8.2% of the base fluid's data points deviate from the mean. The value of the nanofluid is 0.02363, indicating that approximately 82 percent of the base fluid's data points deviate from the average value. When compared to normal clay, the rheological characteristics, gel strength, and filtrate volume of nano clay illustrated a negative influence on drilling fluid performance and deviate from the API standard specifications. The values for PV, YP and gel strength indicate a high slope trend, however, the filtrate volume collected shows a decreasing slope trend. Results prove that the proposed nanoparticle water-based mud is successful and has reduced the cake thickness by nearly half compared to the ordinary clay. The Hydrophilic smart nano clay introduced here is a new technology. Resources of the material are available in nature and can be obtained with ease and low cost. This investigation outcome is based on solid experimental results and can be implemented in the field without extra efforts or the need for scale-up.
Nano Technology Micro-Emulsion Technology Removed Invert Emulsion Fluid Filter Cake Damage After Delayed Action Across Sandstone Reservoir
Authors: Olivares Tulio Daniel , Al-Zahrani Walid , Latter Kreke , Mukoro Temu 
Published: October 2022

Abstract
The objective of this manuscript is to present the value addition of a Nano Technology based Windsor IV Micro-Emulsion which helped to remove Invert Emulsion Fluid (IEF) filter cake across sandstones reservoirs. Benefits such as delayed reaction, uniform treatment across the reservoir, no losses or well control events and improvements in the well producibility expectations will be presented in this paper.
The approach was to determine the nature of the filter cake and determine an improved process for removing the cake from the well-bore utilizing a Nano Technology based Windsor IV Micro-Emulsion that will solubilize the filter cake through the creation of Micellar Structures in the 2-14 nanometer range. A series of laboratory tests were conducted to ensure compatibility with the formation, compatibility with formation fluid, along with the removal of the filter cake using the new chemical application process. The ICD screens were deployed and filter cake was removed with a minimum delay of one hour to prevent needless losses that could end up with catastrophic well control situations or excessive non-productive time trying to cure the losses to continue with the completions operations
The new chemical blend was mixed and deployed on well A & well B, under capable filter cake removal engineer and using the existing rig equipment with no operational issues. Both wells retained intact filter cake for at least a 2-hours period, thereby preventing initial losses and avoiding an LCM pill being pumped to cure the losses, that could result in formation damage or affect the permeability of the production formation. As demonstrated in the laboratory tests, full filter cake removal was achieved in a 12-24 hours period. In wells A & B, we did not experience losses within the time period required to run the upper completion and close the isolation safety valves. The conclusion from the field application is that this Nano Technology based Windsor IV Micro-Emulsion demonstrated the ability to remove the IEF Filter Cake in a controlled manner, allowing the drilling rig completion operations to be run without any interference or additional steps and after the soak period the wells A & B were opened to show improved Productivity Index post application.
The drilling-petroleum industry is continuously looking for technologies to improve the return of investment and maximize the wells producibility, definitely the introduction of this new Nano Technology based Windsor IV Micro-Emulsion package to the area of IEF Filter Cake removal will bring benefits and value to this purpose as was demonstrated after the implementation on wells A & B in the studied area.
First Industrial High Power Laser Field Deployment: Lab to Field
Authors: Batarseh Sameeh I. , Mutairi Saad M. , SanRoman Damian P. , Assiri Wisam J. 
Published: October 2022

Abstract
This paper presents the industry's first successful high-power laser field deployment and the strategy that led to this success, including lab-to-field transformation. This paper will also give an overview of the intensive research conducted over the past two decades, recent field deployment and plan forward.
Laser technology is used widely in almost every industry, from medical to the military, due to its unique features, such as precision, reliability, control and accuracy. The oil and gas industry capitalized on low-power laser applications such as sensing and measurements, but high-power laser applications remained beyond the realm of upstream. The program described in this paper aims to resolve it. To reach this goal, a strategic plan was designed around four pillars: laser-rock interaction, optomechanical design, energy delivery, and sustainability. The first pillar focused on developing a comprehensive experimental database of laser-rock interactions, which included tests on all types of rocks under different conditions. The second and third pillars concentrated on tool development and energy transmission via optical fibers. The last element analyzed how high-power laser applications enable sustainability in subsurface applications. The result is a comprehensive experimental database with thousands of tests and a robust field unit that can withstand harsh field environments. The system's design is enclosed, providing a safe and risk-free operation. The system consists of a laser energy generator, nitrogen tank, vacuum truck and tool.
The success of the intensive research conducted over the past two decades led to the development of the first high-power laser system for field applications and unlocked several upcoming applications.
All rock types have been successfully tested under different conditions, including in-situ tests in liquid and gas environments. The experimental plan was designed systematically and divided into phases, from fundamentals to advanced. Prototype tools were designed, tested, and upscale for field deployment. The tools combined optical and mechanical components. Several iterations, modifications, and improvements to the tools were applied until the optimized version was achieved. The laser source generates the laser beam (energy) at the surface. The power is transmitted via protected and shielded fiber-optic cables to the downhole tool, which is designed to control the geometry of the beam. High-power laser technology has been proven to effectively penetrate and drill in all types of rocks regardless of their strength and composition
High-power laser technology is an innovative alternative to current methods such as perforation, descaling and drilling. It is cost-effective, compact and environmentally friendly, providing sustainable operations. The advantage of the technology is that several applications can be performed with a single energy source (the laser), and only the tool needs to be changed for different applications.
Metal Expandable Packers Deliver Cement Assurance for Improved Well Integrity
Authors: Hazel Paul Roderic , Wallach Mathieu , Adeniyi Dapo 
Published: October 2022

Abstract
Operators globally are consistently challenged to deliver effective cement sealing for Zonal Isolation (ZI) between reservoir units and to prevent Sustained Annulus Pressure (SAP). This paper discusses such a challenge for a land well drilled in West Africa and how these challenges were addressed. The challenge was to achieve effective ZI of a depleted sand gas reservoir and provide B annulus isolation to prevent future SAP. The challenges arose from a combination of losses (during drilling and cementing) and potential gas invasion into the cement during the cement curing process. The solution utilized three Metal Expandable Packer(s) (MEP), two of which were expanded within wet cement. The MEP purpose is to deliver ZI Cement Assurance (CA) across the reservoir and one MEP set above Top of Cement (TOC) within the Open Hole (OH) to protect the B annulus from (SAP). Both solutions improved the overall well integrity, providing mitigation from cross flow, early water production and the risk of methane emissions release into the atmosphere.
Single Slurry Modification to Improve Well Integrity in NEB Field
Authors: Mahesa Widi , Alsaadi Alhanoof Musabah 
Published: October 2022

Abstract
Based on the history of cementation of 9-5/8″ heavy casing design in NEB field, all the wells are cemented with lead (10.0 ppg – 12.7 ppg) and tail (15.8 ppg), where during the cementation pure cement is gained in surface. Based on the Cement log, the lower area (Tail) is accepted and some discrepancies in the interpretation on the upper section due to tools limited capability in reading light weight cement and presence of dual casings. However, several years after the completion some of the wells have been identified as SAP B (Sustain Annulus Pressure) between annulus 9-5/8″ casing and 13-3/8″ casing.
An advance logging tools was run to one of the recent SAP B wells, that used integrated approach to do interpretation that considers the data from 3-dimensional acoustic sensors, cement bond logs, production data, open hole data logs and recent well operations. The interpretation is most likely scenario for this SAP B is micro-debonding of 9-5/8″ casing to cement which is causing the gas flow to surface; and cement failure below 13-3/8″ shoe with the source of SAP B is in Fiqa formation, while all the formations below Fiqa are acoustically quiet and no annular flow is happening from deeper reservoirs.
As per standard practice, in such situation the SAP B must be cured prior to re-complete the wells. To cure the SAP B, section milled across aquifer (RUS and Dammam) will be performed, followed by plug and squeeze across the milled section and later will be run with 7″ tie back cementation to surface. Performing these steps will require minimum 5 days prior to re-run completion string.
To improve well integrity in annulus between 9-5/8″ casing and 13-3/8″ casing, a dependable barrier for long term well integrity should be provided. A novel approach involving single cement slurry modification with expansion properties was discussed by adding post set crystalline material into cement design and tailored it to have expansion effect to minimize micro debonding and micro channeling. In parallel, maintaining slurry fluid loss properties is also critical to provide better cement bond. By changing the cement design into single slurry, the potential of losses will rise during cementation and might end up with poor zonal isolation in the annulus. Other aspect taking part as consideration is by using adequate spacer volume with engineered rheological properties for better cleaning, maximize both centralization and pump rate since pipe movement (rotation and/or reciprocation) is not an option.
The job was planned to be performed in single stage cementation, with maximize the centralization profile, use sufficient volume of spacer, then followed with pumping single slurry expandable considering adequate excess of open hole and displacing with maximum rate using the rig pump for better displacement efficiency.