bluuebunny/crossref_metadata_2025_split huggingface dataset:
Models for Calculating Corrosion Rates in Water-Saturated and Under Saturated CO2 Systems & Water Solubility in CO2 Systems at Supercritical Conditions
Authors: Kowta Rama , Erickson Dale Douglas , Barker Richard , Neville Anne , Hua Yong 
Published: April 2022

Abstract
In water-containing dense phase CO2 environments, which are typical conditions seen in Carbon Capture and Storage (CCS) systems, corrosion rate increases in conjunction with humidity, typically reaching a critical humidity, beyond which corrosion rates become particularly high. In this work, we discuss the development of a model to calculate corrosion rates in CO2 systems, both pure as well as those containing impurities, with under-saturated water content at dense and supercritical conditions.
A new model is developed to predict corrosion rates in CO2 systems, both in presence and absence of impurities, with under-saturated water content at supercritical conditions while existing in-house models are used to predict corrosion rates at saturated water content. The model to calculate corrosion rates at under-saturated water conditions uses the solubility of water in CO2 rich phase at saturated conditions. A Peng-Robinson equation of state, E-PPR78, available in literature, is modified further to match water solubility in CO2 rich phase in the presence and absence of impurities at supercritical conditions and on both sides of the two phase-region.
We present results from the modified E-PPR78 model, validating calculated water solubility in the CO2 rich phase against experimental data available in literature for pure CO2 as well as for CO2 systems with impurities. The results presented cover a wide range of pressures and temperatures both in sub-critical and supercritical regions. For pure CO2 with water system, the error in the calculated water solubility in CO2 rich phase is less than 4% in sub-critical region and is less than 7% in the super-critical region. The presence of impurities in the CO2 stream influences the solubility of water and hence, the humidity and corrosivity of the CO2 stream. We present calculated water solubility of water in CO2 rich phase in CO2 and N2 mixture for different N2 concentrations and validate it against experimental data found in literature.
An empirical correlation was developed based on experimental data to predict corrosion rates in CO2 systems at under-saturated water conditions in the presence of impurities. The empirical correlation to calculate corrosion rate at water under-saturated conditions uses corrosion rate at water-saturated conditions, calculated from an in-house tool, and the water solubility in CO2 rich phase, calculated from modified E-PPR78 equation of state model.
Taking Subsea Operations to the Next Level by Applying Machine Vision to Perform Autonomous Inspections
Authors: Johansen Kristoffer 
Published: April 2022

Abstract
DeepOcean and partners have for multiple years been developing an Autonomous Inspection Drone (AID). This is a remotely operated vehicle designed to perform high-quality inspections of subsea assets. The AID is equipped with a state-of-the-art machine vision camera, which is used to autonomously navigate through a pre-programmed inspection scope. The operation of the AID is supervised by our remote operation center in Haugesund, Norway. This paper presents results from our first field trial.
A digital twin was constructed for multiple subsea templates. The digital twin was developed into a game where a model of the AID was controlled. This allowed inspection engineers to plan the route for the inspection. The planned route in the digital twin was exported to the AID. The AID autonomously executed the planned route. Autonomous navigation was made possible by combining an inertial navigation system, a USBL positioning system and a machine vision camera. The machine vision camera detected QR-codes on the subsea asset. This allowed the AID to correct position and determine the true location on the asset.
Multiple tests were performed during this field trial. Observations of these tests are presented in the paper. Examples of tests that were performed during the field trials include autonomous undocking and docking from TMS, executing of pre-programmed inspection route and station keeping when QR codes were detected on the subsea asset. It was observed in the field trials that the control system to the AID would need to be further developed. This is to increase the robustness and enhance the efficiency of autonomous navigation. These considerations are discussed in the paper, and conclusions are drawn with regard to how this may be achieved.
This paper will explain how DeepOcean planned and executed an inspection scope by combining a digital twin of the asset and a machine vision camera used to assist the navigation of the AID. The results and conclusions presented from this field trial are essential for the petroleum industry to step into a future where resident vehicles are able to perform value-creating work autonomously. In the near term, this work is forming the foundation for DeepOcean to increase the performance of simultaneous operations from our vessels. This will be made possible as the AID may be launched from the vessel, which is completing some other intervention work, and come back after the autonomous inspection has been completed. The operation may be supervised by our control centre in Haugesund, Norway
Through Drillpipe Formation Testing: Unlocking Bypassed Pay, A Case Study Onshore Kuwait
Authors: Tagarieva Larisa , Chacon Eduardo , Olutusin David , Sindhu Sneh 
Published: April 2022

Abstract
Identifying a bypassed pay is always challenging, especially for highly deviated, complex wells where well control further complicates wireline logging. This case study examines the use of a Through Drillpipe Logging (TDL) conveyed formation testing and sampling tool in addition to the conventional slim open hole logging suite. The logging program overcame the challenging well trajectory and wellbore stability complications. The resulting data provided a conclusive formation evaluation and reservoir characterization identifying bypassed oil.
The logging program targeted two formations: The primary goal was the Upper Burgan and the secondary target, a suspected bypassed pay, was the Lower Burgan. The well was highly deviated and was drilled with the oil-based mud system. In addition to the complex trajectory, a well bore stability was identified as marginal due to observed washouts. Therefore, the logging program implemented TDL for both traditional open hole logging and formation testing and sampling TDL pumps the tools down the drill pipe ID until reaching TD, where they are released into the well bore and logged back to surface. On the first acquisition run a triplecombo logging suite was run, and a complete dataset was acquired without any differential sticking. During the second run the slim formation tester was centralized to minimize sticking risk during the planned stationary acquisition of formation pressure measurements and sampling.
The TDL conveyance of slim logging tools eventually led to enhanced reservoir understanding and characterization after the data interpretation. Specifically, 22 pressure points and 2 low-contamination samples were returned to surface. The sampling series found fluid in the secondary target. The combination of pressure data, porosity, saturation, fluid mobility, and permeability data characterized the formation. This combination resulted in a deeper understanding of the storage and flow capacity of these heterogeneous reservoirs. Consequently, the well completion design was optimized by the producer.
The TDL conveyance option helped to safely log the well from TD in a complex trajectory by pumping down the slim-logging tools to avoid differential tool sticking across a major washout. Regular tool fishing operations were eliminated, and open-end drill bit usage allowed reaming during wiper trips between the logging runs. TDL significantly reduced operational risks optimizing rig utilization and minimizing overall costs in addition to reservoir and formation fluid data acquisition.
The slim formation testing of the Burgan reservoir supported completion of the primary well objectives and identified bypassed pay in the secondary objective. The field development and exploratory strategies were updated based on the logging results.
WindFloat Atlantic Project: Technology Development Towards Commercial Wind Farms
Authors: Duarte Tiago , Price Seth , Peiffer Antoine , Pinheiro José Miguel 
Published: April 2022

Abstract
This paper presents the main achievements of the WindFloat Atlantic project, the first pre-commercial wind farm using semi-submersible technology. The journey from initial technology development through the project execution is discussed, with the viewpoint of upcoming commercial deployments. Following the successful deployment of the WF1 prototype, the WindFloat Atlantic is a 25MW floating wind farm composed of 3 semi-submersible platforms hosting 8.4MW wind turbines. The wind farm has recently completed the first year of operation, 17km off the coast of Viana do Castelo.
Key technology requirements were developed, implemented, and demonstrated, including an extended design lifetime of 25-years, building on the knowledge of oil&gas permanent units and fixed-bottom offshore wind. The use of large commercial turbines required a quay-side assembly process, with turbines installed with the foundations a float or temporally grounded. By using an onshore crane, the project avoided the use of large offshore heavy-lift vessels, also allowing most of the commissioning works to be completed onshore. The offshore activities were greatly simplified, being designed to allow a tow-to-port O&M strategy for large component replacement. Following a multi-contract strategy, the project fostered the development of the value chain and the processes required to install multi-unit offshore wind farms.
Furthermore, the project achieved non-recourse finance from EIB, demonstrating the bankability of the technology and representing a step-change towards the readiness of floating wind technology for large commercial deployments.
Analytical Model to Effective Permeability Loss Prediction and Formation Mechanical Damage Control in Fractured Oil Wells
Authors: Fernandes Fernando Bastos , Braga Arthur Martins Barbosa , de Souza Antônio Luiz S. , Soares Antônio Cláudio 
Published: April 2022

AbstractThis work presents a new analytical model to evaluate the effective permeability response during the oil’s production through a fractured vertical well fully penetrating a pressure-sensitive reservoir. The nonlinear hydraulic diffusivity equation (NHDE) is solved analytically through an integro-differential model coupled to Green’s function (GF) related to a semi-infinite oil source plan that represents a hydraulic fracture. The NHDE is perturbed using a first-order asymptotic series expansion method and the solution is derived in terms of a new effective permeability pseudo-pressure function, considering the matrix and fracture permeability roles. A new hydraulic diffusivity deviator factor is also derived to represent the effective permeability loss as a function of the pore pressure throughout the well-reservoir life-cycle. For this modeling, the general solution is expressed by the sum of the linear solution (constant permeability) plus a corrective term given by the combination of the exponential function and the complementary error function erfc(yD,tD). The model calibration is performed through a porous media numerical oil flow simulator, named IMEX® and the results presented high accuracy.
Boosting Reaction Rate of Acids for Better Stimulation of Dolomite-Rich Formations
Authors: Sayed Mohammed A. , Cairns Amy J. , Chang Fakuen 
Published: April 2022

AbstractCarbonate formations are often stimulated using acid systems to enhance production rates. The reaction rate between acid and dolomite is known to be much slower than that between acid and calcite. Accordingly, for some acid fracturing treatments in dolomitic formations, it has been observed that the injected acid system could not adequately react with the rock to render desirable etching patterns on the fracture faces. This can be a direct result of the slow reactivity between dolomite-rich formations and acids. Developing an acidizing fluid that can accelerate the dissolution of dolomite will be beneficial to maximize the results of stimulation treatments in dolomite-rich formations.In the current study, advancements were made toward accelerating the reaction rate of dolomite with acids through an additive-driven chemical approach based on careful surfactant selection. Static dissolution testing of dolomite core samples in the presence of 28 wt% hydrochloric acid (HCl), both with and without additives, were performed at ambient conditions. The weight loss was calculated, and the efficiency of the added chemicals was evaluated to select the formulation for evaluation at reservoir conditions. A comprehensive reaction kinetics study was performed at a pressure of 3000 psi, across a temperature range of 175 to 350 °F. Guelph Dolomite samples were cut into 1.5" diameter by 0.5" thick disks. Powder X-Ray diffraction (PXRD) was used to determine the mineralogy and purity of the dolomite core samples. The ion concentrations in the effluent samples during the dissolution was measured by ICP in the effluent samples.Several acid/surfactant formulations were screened and characterized in the current work where several suitable surfactants were identified. It was found that the rate of dissolution of dolomite rocks in hydrochloric acids (28 wt%) could be increased by up to 30%. These results are consistent with the kinetics data collected at both 200 and 300 °F, where the rotating disk apparatus (RDA) showed that the reaction rate of dolomite with one of the developed formulations can be improved by 30 to 50% over hydrochloric acid alone.The acid/surfactant formulations developed in the current study are aqueous-based formulations. There were no incompatibilities observed after the fluid preparation. The developed acid systems showed an improvement in the dolomite and acid reaction rate which paved the road to apply these formulations in the field to improve the outcome of acid fracturing treatments.
Generating Value from Inspection Ground Robots on Operational Sites
Authors: Munoz Jean-Michel , Bartoli Eric , Audouin Grégoire , Collin Gildas , Mateen Khalid 
Published: April 2022

Abstract
Over the past few years, many communications were made by robot manufacturers showing inspection robot prototypes on production sites. As the first autonomous and explosion proof inspection robots become commercial, and even if oil & gas operators are more and more interested, many have difficulty seeing how value can be generated with this new tool. This paper will describe TotalEnergies' journey towards robot implementation on site.
TotalEnergies' use of robotics on site comes from a vision of a new operating philosophy where sites will be unattended for very long periods. Based on the activities that need to be done between human interventions, TotalEnergies engaged in the development of different types of robots. Even though robots are new tools, they must comply with existing operating procedures as much as possible to be adopted by field operations teams. Among the points that require special attention for efficient operations, are robot capabilities, mission planning, data post-processing and full integration of the robots into the company's IT systems.
The best way to get robots fit for purpose for an oil & gas operator is to be able to weigh in on the robots' specifications by providing the manufacturer challenging use cases. Doing so, features like explosion proof design, autonomy, long arm and more become obvious.
Expectations from field operators are quite high when a robot is on site. They imagine that the robot will "start doing things", not realizing that the robot is an empty shell even if it is autonomous. To prepare operations with robots, a digital model of the installation must be available, and a maintenance/operation engineering exercise must be done to highlight the step-by-step instructions that will be given to the robots. The difficulty with the data collected by the robot is that it can rarely be used directly as we do for numerical values coming from transmitters. In most cases, the interesting information like a value, a status open/close or on/off, needs to be extracted from an image, a video or another support by artificial intelligence.
Finally, the robot cannot be an independent piece of equipment on site and must be treated like any other package by the site control system.
Starting with TotalEnergies' roadmap on robotics, the paper will give feedback on various field trials from different sites, combining altogether nearly one thousand missions. Then, a focus will be made on how to prepare and integrate robotics operations on site to be able to scale up and open this new frontier for improved safety, reduced environmental footprint and costs and increased production efficiency.
Competitive System Concepts for Electrification of Subsea Structures in Co-Existence with Electro-Hydraulic Control Systems
Authors: Sommer Burkhard , Mahler Carsten , Stables Gary , Mitchell Lee 
Published: April 2022

Abstract

Objectives/Scope
Subsea production systems can benefit today from the application of partial electrification concepts in hybrid scenarios coexisting with electro-hydraulic (E/H) control systems. This paper is based on a real project that included a system of conventional E/H subsea production trees, manifolds, and a boosting station, together with a subsea distribution and control system. Based on this architecture, an alternative field concept optimized for partial electric actuation resulted in very competitive commercial scenarios in addition to operational benefits and increased sustainability.

Methods, Procedures, Process
Using electric actuators for valves on subsea production system structures is becoming more common but is still limited. The reason for this limitation is that the systems are often not fully optimized for these uses. There are operational and conceptual differences between traditional electro-hydraulic systems and electric actuation systems. For many years subsea engineers have applied proven field and system concepts and established work practices to field development and subsea control scenarios, which might not have been successful if applied to electric actuation without further change. Electric actuators cannot replace hydraulic actuators without also rethinking the underlying system architecture.

Results, Observations, Conclusions
When alternative configurations were analyzed, the basic architecture was maintained. But instead of simply replacing the hydraulic actuator with electric actuators, it was important to consider how the actuators were connected to the control system in terms of distance, communication, and overall layout. Holistic optimization of the subsea distribution and control system introduces significant benefits to the whole system. However, electric actuators have different performance and diagnostics characteristics than hydraulic actuation systems. Specific sessions were held with the operator, focusing on system performance and the operational advantages of the proposed system. The subsea distribution system and its control philosophy were changed from a traditional layout to a layout taking full advantage of the benefits electric actuators are offering.
This paper uses before-and-after comparisons to show how moving from traditional subsea control methods to a "hybrid" system enables a more sustainable architecture by combining "traditional" products with newer electric actuation methods. As a result of those benefits, the end user in this case study selected the hybrid system and replaced the original base case.
Automated Subsea Pipeline Leak Detection Using Real-Time Downhole Gauges
Authors: Kadem Mohammad , Bayounis Ryyan , Jawad Mustafa , Ghamdi Tareq 
Published: April 2022

Abstract
In oil industry, there are several technologies used in detecting subsea pipeline leaks. These technologies are not costly only, but require extensive implementation fieldwide across hundreds of kilometers pipelines. Currently, there are few digital solutions or systems in the literature addressing the detection mechanism. In this study, an automated mechanism will be introduced to locate leaks in subsea pipeline network coupled with real-time monitoring.
Real-time downhole pressure data from wells' permanent downhole monitoring systems (PDHMSs) are used to map the pressure drop across each reservoir in water injection subsea pipeline network. The data are collected from the gauges and are fed into the model with the incorporation of reservoir properties data. Monitoring of the possibility of leakages can be done by measuring the pressure of wells. A positive pressure differential in wells represent a maintained injection pressure across the reservoir. Wells with a negative pressure differential show low injectivity which might indicate a potential leak in the subsea water injection pipeline network. A dye injection technology can be used to detect leakages and confirm the model result.
Pressure data from real-time PDHMS gauges are first validated with reservoir simulation models to ensure accuracy of the input parameters. The pressure data validation is achieved by verifying each reservoir data using its properties for reliable reservoir pressure identification. Then, the GAPTM network model can be used to validate the pressure drops. The model results can enable engineers' decision-making process easier to spot leak locations where pressure decreases drastically across the subsea water pipeline. The proposed model also shows a close match with the simulated values from GAPTM network model within an accuracy of 2%. Additionally, a dye liquid is injected into the sea near to the suspected pipelines with leaks. The dye introduces a new color and thus can confirm the leak locations based on calculated values from the automated model.
Pipeline leakages have been a problem for many oil fields with water injection mechanism. Pipeline leak detection is an integral part of pipeline risk management. The model can assist the engineers to locate the leaks proactively and prevent incidents from occurring time to time. The leaked water could damage environment and cause injection rate loss.