Day 3 Wed, February 14, 2024最新文献

{"title":"CO2 Soluble Surfactants Assisted Carbon Storage Under Achievable Pressure Gradients: Effect of Surfactant Partitioning Behavior During Continuous CO2 Injection","authors":"Lei Ding, A. AlSofi, Muhammad M. Almajid, Pramod Patil","doi":"10.2523/iptc-23958-ms","DOIUrl":"https://doi.org/10.2523/iptc-23958-ms","url":null,"abstract":"\u0000 Injecting CO2 into the saline aquifers normally suffers from low sweep efficiency due to the smaller density and viscosity of CO2 compared to brine. The potential of CO2 soluble surfactants assisted carbon storage in carbonate formations was first evaluated by core flooding tests (at 65°C, 150 bar & 90,000 TDS) in Indiana Limestone at different gas fractions, where the surfactants were injected with the CO2 phase (CCI+S). The pressure gradients and CO2 saturation were continuously monitored during the coreflooding tests. It was found that foam was generated during CCI+S when 0.07 wt.% of surfactant was injected with CO2. Moreover, the CO2 saturation at steady states can be significantly enhanced in the presence of foam from experimental observations. The CO2 saturation reached 60% (compared to 32% without surfactant) after 1.5 PV of CCI+S. The maximum pressure gradient was approximately 1.5 psi/ft in 162 mD Indiana Limestone at a Darcy velocity of 1.0 ft./d, which is technically feasible for field applications. Furthermore, an improved foam model incorporating the surfactant partitioning behavior was developed to obtain the foam modeling parameters by history matching the steady-state foam behavior. The effect of surfactant partition on CO2 transport behavior was studied by a 1D synthetic model at a lab scale and 2D synthetic homogeneous/heterogeneous models at the field scale, using modeling parameters and surfactant concentrations that are realistic for field tests. The sensitivity analyses imply that the CO2 storage efficiency largely depends on surfactant partitioning behavior (Ksgw), dispersivity, and formation heterogeneity, etc. The simulation results also indicate that there may always exist an optimal Ksgw for CCI+S, which satisfies both good CO2 sweep efficiency and acceptable injectivity. The advantages of injecting the surfactant with CO2 are more evident in heterogeneous saline aquifers, indicating an enormous potential of CCI+S for carbon storage. The novel injection strategy provides a promising solution for carbon sequestration in saline aquifers.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"7 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527877","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Casing Centralization—Planned Compared to Actual: A Kuwait Case Study","authors":"M. A. Fituri, Y. Ali, A. Al-Naqi, J. Saikia, K. Abdulrahim","doi":"10.2523/iptc-23514-ms","DOIUrl":"https://doi.org/10.2523/iptc-23514-ms","url":null,"abstract":"\u0000 Several reasons can contribute to poor cementation; however, proper casing centralization can lead to uniform mud displacement with cement and can mitigate some of the cementation problems. Cementing companies design their casing centralizations based on simulators, but they have never been able to validate quantitatively how their planned centralization compares to the actual, the only comparison made in the past was based on the overall cement quality measured by the cement evaluation tools. This can be reflective of the centralization program in some instances; however, in others, attributing quality to centralization can be misjudged or centralization may be mixed with other factors.\u0000 Not being able to directly quantify and evaluate each element in the casing and cementation program makes it challenging to improve or acknowledge each design. Relating the achieved cement quality to casing centralization gives inconsistent results. In many instances poor cement behind casing is because of other factors such as spacer design, fluid rheology, formation fluids, borehole geometry, etc., and is not only due to poor casing centralization.\u0000 Casing eccentricity or casing touching outer casing/formation is always observed on cement evaluation imaging logs, as they typically appear in a form of galaxy pattern. However, these galaxy patterns can only be considered as a qualitative indication of the casing being close to a casing or to a formation, as it will be shown later in the paper that galaxy pattern start to show on cement evaluation images when casing centralization is below 60%.\u0000 The new generation of ultrasonic flexural measurement tools can evaluate cement and at the same time provide third interface echo (TIE) measurement over 360°. The TIE measurement can evaluate casing centralization by evaluating the time between the first casing reflection (mud-casing interface) and the third interface reflection (cement formation interface) (Δt). When all the Δt values across all azimuths are equal, it is an indication of casing being 100% centered, and when Δt is 0 or small (casing touching formation) from any direction then casing is 0% centered. This Δt can also be converted to pseudo annulus thickness by assuming a velocity for the material behind the casing.\u0000 For an operator to improve their field casing cementation, a campaign was performed for evaluating casing centralization in multiple casing sizes for different well trajectories to set benchmark for future centralization improvements. Each casing had different centralizer size and different patterns.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"29 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528018","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Decoding the Stratigraphic Heterogeneity of Bengal Basin, India Using Supervised Machine Learning-A Case Study","authors":"Arijit Sahu, Manomita Kundu","doi":"10.2523/iptc-23372-ms","DOIUrl":"https://doi.org/10.2523/iptc-23372-ms","url":null,"abstract":"\u0000 \u0000 \u0000 In oil and natural gas exploration, Machine Learning (ML) has gained noteworthy prominence for its ability to decode complex subsurface geology. ML commonly applies advanced statistical algorithms to build robust predictive regression and classification models. On-land Bengal Basin tasted exploratory success recently but displays great ordeal of stratigraphic heterogeneity. This paper discusses application of support vector machine (SVM), random forest (RF) and self-organizing map (SOM) ML algorithms with supervisions towards comprehensive modeling of the complex Miocene facies from Bengal on-land area for the maiden time, difficult otherwise by subjective conventional approach.\u0000 \u0000 \u0000 \u0000 Advanced geochemical logs (such as Elemental Capture Spectroscopy, ECS) and core data usually are very useful to quantify the facies downhole. However their availability also demands increased operation time and cost. Whenever available such data can be treated seamlessly with ML to test and build quantitative facies classification model from limited resources to over a region. Facies classification by ML not only makes the most of the available data but also eliminates the undesired subjectivity in addressing the subsurface heterogeneity with higher confidence. Gamma Ray, Neutron-Density, Resistivity, Sonic derived P-wave & S-wave velocities and suitably engineered log derivatives are mathematically modeled from the study area to classify facies using SVM, RF and SOM ML algorithms with ECS and core data calibration.\u0000 \u0000 \u0000 \u0000 Miocene sediments of the study area shows presence of six distinct facies viz. Claystone, Silty Claystone, Clayey Sand, Sandy Clay, Sand and Clean Sand. Facies data are trained by ML algorithms with multifold cross validation and returns credible accuracy for SVM, RF and SOM. The statistics driven facies model has been extrapolated for area where ECS or core data are not available but common logs are and yields geologically acceptable outputs. During exploration and field development stages such ML driven quantitative facies model improves the understanding of the subsurface from reservoir and non-reservoir point of view. ML Facies modeling captures the transition from shelf to fluvial depositional environment in the study area. Association frequency of different facies helps to visualize the changes from low/transitional to higher energy regime on a fine scale within Miocene.\u0000 \u0000 \u0000 \u0000 This paper discusses appropriate workflow, SVM kernel selection and hyper-parameter optimizations for SVM, RF and SOM that dictate the quality of facies model for Bengal basin. Heterogeneous stratigraphic play of Bengal on-land area demands accurate and quantitative subsurface lithological understanding for deploying fine exploration and development strategies, which can be addressed by this study. Nonetheless RF/SVM appear to be better facies classifier than SOM for Miocene sediments of Bengal from overall classification accuracy especially for less populous ","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"30 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527787","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Improving Energy Efficiency and Reducing Carbon Footprint of Oilfields Using a Rigorous Multi-GOSP Optimization Platform","authors":"M. Alhuraifi, A. Ghazal, Y. He, R. White","doi":"10.2523/iptc-24647-ms","DOIUrl":"https://doi.org/10.2523/iptc-24647-ms","url":null,"abstract":"\u0000 This work discusses optimizing the operations of a complex gas-oil separation plant (GOSP) network. The objective is to operate this complex network such that the required oil target is produced at minimum OPEX while leveraging the transfer capability between GOSPs. A mixed integer non-linear programming (MINLP) model is developed to optimize swing line production and processing equipment operation. This allows the systematic identification of optimal operating points, which optimizes operations. Consequently, it will result in further reduction in the processing cost and greenhouse gas emissions associated with power generation and flaring.\u0000 Many GOSPs exist to process crude production from oil wells to separate the multi-phase produced fluids into oil, gas and water. These plants include equipment, which are highly energy-intensive such as high-pressure gas compressors and water injection pumps, which are used to boost separated fluids to their final destinations. In addition, transfer lines might exist between facilities allowing for shifting production or part of it from one plant to another. As a result, there is an opportunity to optimize crude oil distribution among plants to improve asset utilization and minimize power consumption. This is in addition to the benefits of reducing greenhouse gas emissions by an average of 10% based on calculations using an MINLP model and Aramco's best practices for optimizing crude oil handling operations. The paper proposes use of parameter generation techniques to improve the model's prediction using data analytics, thereby delivering a digitalized fit-for-purpose application. This results in minimizing energy consumption while maintaining the oil target without added investment (neither OPEX nor CAPEX). Consequently, it will result in further reduction in the processing cost and greenhouse gas emissions associated with power generation.\u0000 This paper proposes a novel methodology to formulate and achieve a desired optimization solution. It also describes the level of fidelity used to model physical process equipment. This varies between use of detailed first-principles models in certain equipment to a more simplified representation elsewhere. This is done systematically based on the overall impact on the solution's accuracy and robustness.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"21 6","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527790","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Navigating Error Reduction: An Investigation of Enhanced Reality Technology and Operator Competency","authors":"Ahmed Alaa","doi":"10.2523/iptc-24631-ms","DOIUrl":"https://doi.org/10.2523/iptc-24631-ms","url":null,"abstract":"\u0000 The baby boomer generation continues to retire and turnover in the process industry (the great resignation) is impacting many manufacturing sites with severe ‘brain drain’ at all levels, especially operators. The industry is searching for ways to make onboarding of new hires and plant specific qualification more efficient and effective. Traditional methods, like classroom training and shadowing experienced colleagues and SMEs for an extended period of time, are important but no longer sufficient.\u0000 Moreover, these traditional ways to pass on procedural knowledge tend to be highly dependent on the individual (people), which hinders standardization. Over time, shifts develop different ways of doing things, departing from the original procedure or taking shortcuts. In many instances, this leads to practice in the field not reflecting the written procedure. Our industry has a clear need for more transparency and a higher level of control over the practical procedural knowledge of the workforce (tribal knowledge), as well as a way to check and measure the level of operator knowledge and procedural compliance.\u0000 In addition to the shortcomings of traditional training, a common cause for practice in the field not reflecting the written procedures is that the ‘procedure clarity’ is often suboptimal due to the ambiguities or general statements in the procedure steps.\u0000 These challenges and shortcomings directly impact operational productivity due to long onboarding times and unplanned equipment downtime as a result of operating errors. They also directly impact plants’ safety performance, especially where actions cannot be automated and secured by safety instrumented systems. The flawless interaction of operators with the asset is an important layer of plant safety.\u0000 Enhanced Reality technology has been proven to solve the challenges described above. It allows simulating standard operating procedures in a photorealistic 3D environment (digital replica) for users to review, practice and test on standard operating procedures on-demand and on any device. Manufacturing organizations can capture their practical procedural expertise (Tribal Knowledge) and are able to measure and track procedure competency across their operators. This methodology has been labelled Digital Twin of the Person (DToP) by Gartner (1), referring to the human-centric approach of this technique.\u0000 Our presentation will include case studies from some of the process industries biggest companies that demonstrate the impact of improved procedure clarity and more consistent execution, which reduces unplanned events and speeds up operator onboarding while capturing more ‘tribal knowledge’.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"42 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528164","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Erosion Mitigation During Testing of High Deliverability Gas Well - A Case Study","authors":"I. A. Bashir, S. Inam, M. Sana-ul-hussnain, I. Shafee, M. Aijaz, R. Ullah, M. Haider, H. A. Qureshi, M. Khan, H. Ahmad, F. R. Awan","doi":"10.2523/iptc-23511-ms","DOIUrl":"https://doi.org/10.2523/iptc-23511-ms","url":null,"abstract":"\u0000 The paper details the case history of a highly challenging, high deliverability exploratory gas well that was successfully drilled and completed in the frontier region. The 4,900 m well encountered multiple reservoirs during drilling with severe losses in the topmost prospective limestone reservoir formation. Subsequently, well was cased and Drill Stem Test (DST) was performed to test reservoir deliverability. During testing, severe leakages were encountered at the Surface Well Test (SWT) equipment due to high flow velocities, coupled with Loss Control Material (LCM) and formation cuttings flowback. This led to internal erosion in the equipment, resulting in frequent uncontrolled hydrocarbon release into the atmosphere, posing a high risk for personnel. Consequently, frequent shut-ins for maintenance were necessary. Steps taken to mitigate this issue are discussed and recommendations are proposed for future encounters.\u0000 A systematic approach was adopted to offset the effects of erosion and consequential leakages. Points were identified which were prone to leakages, and successively, steps were taken to minimize bends. Non-intrusive thickness monitoring was carried out regularly to detect reduction(s) in the pipe schedule preemptively and take appropriate measures. Erosional velocities were computed for different pipe sections and sufficient back pressure was applied to reduce flow velocity. Other measures such as reducing flowing times at higher chokes and acid stimulation were also carried out to minimize the impact of, and dissolve, the particles eroding the equipment.\u0000 Significant improvements were observed after taking preventive measures – Non-Productive Time (NPT) was reduced, and the remaining job was carried out safely without any impact on the personnel, equipment, environment and the Company reputation. Accuracy of the collected data also improved, as particles had inadvertent effects on flow measurements.\u0000 An extensive study was carried out followed by on site actions to reduce the erosional impacts on a high pressure, high deliverability gas well. Important conclusions were drawn. Safe practices were developed to avoid future occurrences in high volume wells. A combination of steps such as re-arrangement of SWT setup to minimize bends, monitoring pipeline thickness using ultrasonic thickness meter, minimizing flow duration at high chokes, calculating downstream pressures required to limit erosion and applying back pressure, and performing acid stimulation can all help future operations to be carried out safely without any untoward downtime. In addition, dissolvable / degradable LCM could be opted in future wells, and wellbore hydraulics could be further studied to ensure optimum hole cleaning for effective cuttings removal.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528026","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Proppant Pack Stability Enhanced by the Combination of New Fiber Technology and Resin- Coated Proppants","authors":"Franck Salazar, Pedro Artola, Salguero Bruno, Byron Delgado, Santiago Aguirre, Luis Peñaherrera, Jacqueline Boas, Nancy Ormaza","doi":"10.2523/iptc-23413-ms","DOIUrl":"https://doi.org/10.2523/iptc-23413-ms","url":null,"abstract":"\u0000 Hydraulic fracturing has been used for many years as an effective stimulation method in high- and medium-permeability formations where, in contrast to low-permeability formations, the objective is to create a highly conductive proppant pack that bypasses the formation damage. Proppant flowback can affect the stability of the proppant pack and lose the required conductivity in the near-wellbore area. The present work shows how the proppant flowback was significantly decreased by the combination of new fiber technology and resin-coated proppant (RCP) without affecting the productivity index.\u0000 Many methods to prevent proppant flowback have been used successfully, but when challenging production conditions are encountered in high- and medium-permeability hydraulically fractured wells, these methods have been proven ineffective. Low closure stress, high flow rates, high pressure drawdown, multiphase flow, high-viscosity fluids, and stress cycling are some of the conditions that favor proppant flowback. The combination of new fiber technology with RCP has been demonstrated to be effective in controlling the return of proppant in wells that were hydraulically fractured by an operator in Ecuador. The new fibers increase the frictional forces between the chemically resin-bonded proppant pack grains by creating a random network of fibers around the proppant grains. The proppant pack stability is increased by the combination of the two mechanisms. The fibers provide additional particle-to-particle mechanical bonding due to friction increase at the contact point, and the RCP provides chemical bonding.\u0000 Initially, wells were treated only with RCP but as more challenging conditions were encountered, RCP by itself became ineffective; then, the new proppant flowback fibers were introduced. The new fibers provided better adhesion between the fibers and the proppant, which significantly increased the proppant pack stability and created a long-lasting conductive proppant pack. The combination of the two methods was implemented starting in 2022 in 15 wells in the Oriente Basin in Ecuador. These wells have reported no proppant flowback under harsh production conditions like stress cycling and high production rates in intervals with few perforations. The incorporation of a more stable proppant pack has allowed the operator to flow back the wells at higher initial flowback rates. This has resulted in a cleaner fracture proppant pack and higher post-fracture production rates.\u0000 The combination of RCP and new proppant flowback fibers provided maximum flowback control without affecting the productivity index. The addition of the fibers provides better proppant pack consolidation, and this starts as soon as the fracture closes without requiring waiting for the resin bonding activation by temperature.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"27 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528048","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Innovative Logging Methodology and Design to Acquire Data in Challenging Multilateral Horizontal Wells","authors":"H. S. Aljuaydi, S. X. Mehmood, H. M. Aljassem, I. I. Miftakhov","doi":"10.2523/iptc-23519-ms","DOIUrl":"https://doi.org/10.2523/iptc-23519-ms","url":null,"abstract":"\u0000 Acquiring high quality downhole production contribution data for multilateral wells is essential to quantitatively evaluate reservoir performance. The complexity of multilateral completion design and unavailability of advanced logging tools act as innovation drivers to address existing challenges and enhance the current equipment menu in the market. This paper presents an upgraded version of both logging hardware and approach which ultimately resulted in significant improvements of lateral accessibility and data quality.\u0000 The upgraded logging tool utilizes the Total Flow Systems (TFS) which comprises of passive acoustic measurements and multiple active response sensors: temperature, and pulse neutron tools (PNL) in water flow log under different well conditions. The spectral acoustic recording system captures acoustic signals generated by fluid movement across a wide range of amplitudes and frequencies within an extended scanning radius. A numerical flow modeling was utilized to quantify inflows corresponding to temperature gradient changes within the active zones. The phase split is then integrated via simulation model given the inputs of water profile provided by PNL.\u0000 Implementation of the upgraded version showcases high-resolution production profile eliminating the need for mechanical spinners utilization. The generated numerical temperature modeling provided accurate interpretation to the effective production zones in the horizontal section. The analysis of the data collected from two laterals of well P-1 clearly demonstrates that the primary oil production comes from the motherbore, with the oil distribution profile being evenly spread along the entire open hole section. Temperature data from lateral indicates its subdued performance, characterized by a high water cut in the produced fluid. Quantitative analysis of flow profile for well P-2 suggests the top of the logging interval inside the motherbore was contributing around 80% of the oil inflow, whereas the lateral was dominated by uniform inflow. In addition, the majority of water inflow in the lateral was located across bottom depths. In both laterals, inflow zones detected by acoustic sensor during flowing condition had uniform signature. The absence of localized noise events confirms matrix flow without fracture flow contribution.\u0000 The new methodologies and upgraded hardware proved that it can be used as the new standard for production logging in challenging wellbores for production optimization and better reservoir management. The data analytics features improved the decision-making process and accurately represented the reservoir condition.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"14 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528051","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Sulfate-Based Scales: Why Sulfate Ion Concentrations Matter","authors":"N. Almulhim, F. Alotaibi, M. Rafie, T. Alrufail","doi":"10.2523/iptc-23383-ms","DOIUrl":"https://doi.org/10.2523/iptc-23383-ms","url":null,"abstract":"\u0000 Waterflooding is frequently applied in oil and gas reservoirs to sustain the reservoir downhole pressure and achieve a high rate of hydrocarbons production. The main challenge of water flooding is the potential to induce mineral scale depositions, especially when the injected water contains a high sulfate content. The objective of this paper is to determine the minimum threshold of sulfate contents present in the injected water that will not lead to mineral depositions through theoretical and experimental work.\u0000 This study will showcase scale simulation and laboratory experiments involving multi-compositional water interactions with various sulfate concentrations ranging from 100 to 5,000 ppm. The study scheme starts by water preparation for the proposed brines, followed by geochemical analysis using Inductive-Coupled Plasma (ICP) to confirm the physical and chemical properties. Afterwards, scale risk assessment was performed using ScaleSoftPitzer™ to evaluate the scaling tendency. Finally, static bottle tests are conducted for a 48- hour testing period at temperatures ranging up to 260°F using HPHT aging cells at different mixing ratios.\u0000 The scaling tendency assessment indicated a calcium sulfate and strontium sulfate precipitation when sulfate content exceeded 300 ppm. Although 5,000 ppm of sulfate content showed theoretically a low scaling index of gypsum and celestine, the scale mass was estimated to be nearly 2,500 and 500 mg/L, respectively at equivalent mixing ratio. Also, it was observed that as the sulfate content increases, the scale severity increases as well. The experimental compatibility tests reinforced the simulation findings, which showed similar result of inorganic sulfate-based scale precipitation that was observed after 48 hrs. testing time.\u0000 The paper shares a system approach for water compatibility assessment and provides different scenarios using both simulations and water-water lab tests to confirm these predictions. It will also highlight how to mitigate the potential risk of scale and formation damage during water flooding.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"37 6","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528348","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Coupled Geomechanics and Reservoir Simulation for Gigantic Naturally Fractured Reservoirs","authors":"Lei Qiao, Meng Shen, Ali Dogru","doi":"10.2523/iptc-23586-ms","DOIUrl":"https://doi.org/10.2523/iptc-23586-ms","url":null,"abstract":"\u0000 The objective of this work is to introduce the features of a new in-house geomechanics simulator. In this work, the capabilities of the new simulator will be demonstrated by applying it to coupled geomechanics and reservoir simulation models based on large-scale naturally fractured reservoirs.\u0000 The 3D geomechanics simulator presented here utilizes the finite element method (FEM) and was developed in C++. The geomechanical grid is created by extending the reservoir into burdens. The simulator is fully parallel using the message passing interface (MPI) library. The geomechanics simulator is developed as a standalone module and the data exchange (pressure, permeability) with reservoir simulator is performed using the multiple program multiple data (MPMD) paradigm. Faults and discrete fractures are modelled by ‘equivalent material’ constitutive relation, in which multi-fractures are included in a straightforward manner. Plasticity is modelled using an implicit closest point projection algorithm in the finite element context.\u0000 The in-house geomechanics simulator supports three modes: initialization only, one-way coupling, and two-way coupling. It supports poroelastic and poroplastic modeling for intact rock and discontinuities (faults and discrete fracture), e.g., transversely isotropic material (TIV) and Mohr-Coulomb plasticity. It allows users to specify burden grids and stress boundary conditions. It provides permeability correlations for intact rock and discontinuities, including classic correlations like Kozeny-Carman. Users can also define the permeability correlation through table input. The simulator outputs 3D stresses, strains and plastic strains, displacements, and faults displacements and strains. Results can be visualized using industry standard tools as well as open-source tools such as ParaView. Results of the coupled simulation have been verified against industry-standard simulators. The simulation of a billion-cell model has been performed to demonstrate the capability of the in-house simulator for studying gigantic field models.\u0000 This work introduces a new in-house geomechanics simulator that is coupled to an in-house reservoir simulator. It demonstrates the capability to simulate billion cell reservoir models with natural fractures. Use of the multiple program multiple data (MPMD) paradigm via MPI offers a significant improvement in performance and efficiency when compared to a traditional file-based approach.","PeriodicalId":518539,"journal":{"name":"Day 3 Wed, February 14, 2024","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527798","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}