Day 1 Wed, March 15, 2023最新文献

{"title":"Prediction of Flow Control Devices Performance in SAGD Producers Subjected to Sand Impact Erosion","authors":"M. Irani","doi":"10.2118/212766-ms","DOIUrl":"https://doi.org/10.2118/212766-ms","url":null,"abstract":"\u0000 Over the last decade, the Steam Assisted Gravity Drainage (SAGD) thermal recovery process has been successfully commercialized in a range of applications located in the oil sands of Western Canada. Prevention or remediation of SAGD production wells due to slotted liner erosion or high gas/steam production later in the life of the well pair requires a change in basis of design of the completion that is compatible with specific well challenges of these applications and facilitates drainage control while overcoming additional pressure drops due to impaired or plugged-off sand control. Flow Control Devices (FCDs) have demonstrated significant potential for improving recovery in SAGD production wells. However, for most operators the results with FCDs have been mixed or negative, that mostly correlated to either bad design or impact of erosion. A common practice to evaluate erosion is correlation suggested by American Petroleum Institute recommended practice 14E (API-14E). Although due to simplicity API-14E equation became popular, its predictions are quite questionable. Furthermore, quantifying FCD reliability through time and degradation of its performance due to erosion and plugging is key to understand their interaction with reservoir in long-run. Currently distributed temperature sensing (DTS) monitoring are vastly used for SAGD producers to improve the interpretation on their long-term performance. Although DTS helps to identify the hot-spots but it cannot identify steam flashing. In an effort to optimize FCDs operators also required to know the flowrates at each FCD, and till this point distributed acoustic sensing (DAS) acquisitions could not be helpful.\u0000 This work is a continuation of a previous publication discussing near wellbore flashing in SAGD producers (Irani et al., 2020). As discussed in previous publication the near wellbore flashing causes a reduction in the relative permeability of the liquid phase, which creates a new equilibrium that stabilizes at lower drainage rates. But it also yields to higher steam rates at sandface. Steam inflow has two-fold effect on FCDs performance, firstly, increase in steam quality yields to high chocking, and secondly, it creates sand-instability at the sandface that yields to high erosion rates. In order to design and optimize FCDs for SAGD, it is necessary to characterize different FCDs subjected to erosion using actual field data. In this study, to estimate how FCD performance has evolved with respect to erosion, the mathematical framework is presented that honors both DTS data and measured production evolution during the life of the wells. The predictions of this mathematical model were compared with actual erosion locations that was measured with downhole ultrasound-based imaging technique. And it was only few meters away. Implementation of this type of analysis can help operators in evaluating the effectiveness of different type of FCDs, whether they are primarily momentum- or frictional-based ","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"75 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116608756","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":"An Analytical Approach for Optimizing the Subcool of Non-Condensable Gas (NCG) Assisted Heavy Oil Production: Predictions & Limitations","authors":"G. Rosi, Da Zhu, H. Izadi, Mahdi Mahmoudi, Vahidoddin Fattahpour, Morteza Roostaei, Aubrey Tuttle, J. Stevenson, Colby Sutton, I. Gates","doi":"10.2118/212768-ms","DOIUrl":"https://doi.org/10.2118/212768-ms","url":null,"abstract":"\u0000 NCG is increasingly being co-injected with steam in heavy oil production systems to reduce heat loss and greenhouse gas emissions, as well as to maintain reservoir pressure. Given increased use of NCG co-injection, the validity of conventional subcool models must be revisited since they assume that the steam chamber is comprised of water alone. The current study makes modifications to the pure-steam hydrostatic subcool model, as well as the Yuan & Nugent (2013) subcool model to account for the presence of NCG in the steam chamber. Using typical values from the Athabasca oilfield, the study then compares the liquid-height predictions made by the original and modified models and proposes rules-of-thumb that correct for the presence of NCG. In general, increasing NCG in the steam chamber results in a reduction in subcool relative to pure steam. According to modified hydrostatic model, to achieve a liquid-pool height equal to that of pure steam injection, the subcool must be increased by 0.60K per 1% increase in the vapor-phase molar fraction. In contrast, over a wide range of production rates and drawdowns, the modified Yuan & Nugent (2013) model predicts that to achieve a liquid-pool height equal to that of the pure steam case, the subcool must be increased by 0.66K per 1% increase in the vapor-phase molar fraction. Despite the rule-of-thumbs being qualitatively in line with expectations, they suffer from the inability to accurately calculate subcool from field data. The final section of the paper reviews limitations of subcool as a well performance metric and proposes an alternative method of assessment that relies on data that are more readily available to operators.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"225 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133858047","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":"Novel Inflow Control Device Bridges the Gap Between Passive and Autonomous Technologies","authors":"Floyd Simonds, Liang Zhao, José A. Montoya","doi":"10.2118/212775-ms","DOIUrl":"https://doi.org/10.2118/212775-ms","url":null,"abstract":"\u0000 Operators in need of improved reservoir drainage, increases in ultimate recovery, and delay of unwanted fluid production are faced with a choice between passive and autonomous inflow control devices (ICD / AICD) to manage these issues most effectively. Production challenges leading to this choice are increasing as water production in particular across the globe continues to rise.\u0000 Passive Inflow Control Devices (ICD) have been used with great effect throughout the world. Multiple variants exist using nozzle, tube, or helical designs to balance inflow in long horizontal wells and those with permeability variations. Each type of ICD has various degrees of viscosity insensitivity, with the nozzle-type being seen as relatively viscosity insensitive, which is true when the viscosities of the oil and water are nearly similar. As the viscosities between the two diverge, however, all passive ICD's produce more water than oil at breakthrough for a given pressure.\u0000 As ICD's only delay the onset of water and gas breakthrough, however, the industry moved to develop Autonomous ICD's (AICD), which sense the presence of unwanted fluid without any connection to or intervention from the surface. The majority of AICD devices available currently contain moving parts and require close tolerances to deliver their unique benefits. They were initially specifically designed for light oil applications in long horizontal wells to shut off the majority of produced water overall. While this is desirable in low oil viscosity wells it may not be as effective with increases in viscosity due to the need to produce water in order to produce the oil.\u0000 The design proposed in this paper uses no moving parts, significantly restricts water production in a wide range of crude viscosities, is easily configured for a variety of downhole conditions, and delivers passive ICD performance with AICD benefits using a simple, reliable, and unique design.\u0000 The tool functions to restrict water production progressively as either oil viscosity or water cut increase without ever completely or nearly completely closing to production, which makes it an excellent solution for marginal production wells, younger reservoirs, and wells with lower overall production rates compared to other technologies.\u0000 The paper will discuss the theory of the device's functionality to differentiate between fluids present. Laboratory test results will be shown to demonstrate flow performance as well as API 19ICD[1] testing for erosion, plugging resistance, and mud flow initiation testing. In addition, an example comparing an open hole base case to the new device's performance in a sample reservoir will be discussed.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"124 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121783867","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":"Using Edge Computing and Autonomous Control to Manage and Optimize Well Performance in Cyclic Steam Stimulation Operations.","authors":"Zeshan Hyder, Trevor Holding, Brett Garrison","doi":"10.2118/212753-ms","DOIUrl":"https://doi.org/10.2118/212753-ms","url":null,"abstract":"\u0000 The age of Production 4.0 has made possible the collection of large amounts of data. Proper analysis and eventual effective utilization of this data is still going through its \"trial and error\" period. This is where autonomous control systems can utilize the information being gathered continuously and assist in making real-time decisions that would optimize well production, reduce surface and sub-surface equipment wear, maintain production sustainability (reduce well downtime) and provide economic benefit, all without human intervention.\u0000 The controller agnostic Edge IoT platform provided \"out-of-the-box\" and customized autonomous control to analyze daily average operational data and make recommendations and implement set point changes to manage well optimization and operations. A multitude of different instrumentation was also utilized to determine how additional data would assist in further optimization of well operations and well management through exception. Additional instrumentation included a different controller than the incumbent in the field along with wired and wireless load cells, inclinometers and a regenerative Variable Frequency Drive (VFD).\u0000 The observation period of the pilot lasted approximately 7 months which encompassed the majority of the active production cycle of the Cyclic Steam Stimulation (CSS) operated 24 well pad. 16 wells had the Edge IoT platform installed on them whereas the remaining 8 were \"control\" wells which were managed as per standard operating procedures (SOP) by operations. Analysis of data from dynamometer cards, average surface pumping unit speed and average pump fillage in relation to target speed, target pump fillage and associated minimum and maximum limits, led to implementation of set point recommendations. Field results indicated that the Edge IoT platform was successful in making real-time decisions that led to increased production. Advantages and challenges were both observed in regard to different instrumentation piloted.\u0000 The next generation Edge IoT platform with its system analysis methods, high frequency data access, customizable autonomous control logic and real-time alerts, allows for better data granularity and optimization of well production and operations.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"98 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126896385","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":"An Improved Workflow in Mass Balance Approach for Estimating Regional Methane Emission Rate Using Satellite Measurements","authors":"Jeffrey Y. Bian, J. Leung, Nick Volkmer, Jingwen Zheng","doi":"10.2118/212791-ms","DOIUrl":"https://doi.org/10.2118/212791-ms","url":null,"abstract":"\u0000 Satellite-retrieved methane (CH4) concentration data offers a valuable opportunity for large-scale emissions monitoring. However, its widespread adoption remains challenging due to the data volume and varying data quality. A workflow to estimate the methane emission rate of major hydrocarbon plays based on the mass balance principle using publicly available Sentinel-5P satellite data is presented. This workflow estimates the methane emission rate originating from specific regions. The proposed workflow is applied to estimate emissions from the Permian Basin and the Appalachian Basin in the United States. The results are compared against volumes estimated by other means and reported in the literature. The proposed method is easy to implement and offers promising potential for practical and reliable estimates for long-term regional methane emission monitoring purposes.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"20 1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132268002","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":"Integrating Geochemical Fingerprinting Technology with Reservoir Surveillance Data – A Montney Case Study to Optimize Pad Design in Multi-Bench Development","authors":"Peter Liang, Yuchen Liu, Kate Unick, Troy Curzon, Muqing Jin, Jiang Wu, Faye Liu","doi":"10.2118/212732-ms","DOIUrl":"https://doi.org/10.2118/212732-ms","url":null,"abstract":"\u0000 An integrated approach was taken to utilize geochemistry information extracted from cuttings and produced oil samples to monitor vertical drainage between stacked reservoirs as well as to optimize well density in multi-bench cube development in the Montney play.\u0000 Oil extracts from cuttings were profiled using high-resolution multi-dimensional gas chromatography (GCXGC) identifying 2,000+ compounds. Key reservoir properties such as indicators of oil saturation and matrix permeability were calculated using oil signatures extracted from cuttings. Subsequently produced oil were profiled using the same GCXGC method. Drainage frac height (DFH) and quantitative vertical production allocation by zone was conducted by building a geochemistry-based model and correlating the produced oils back to their contributing intervals represented by the cuttings.\u0000 In this Montney case study, two neighboring pads with different cube designs were investigated. Pad 1 is a 12-well pad with 4 target benches and a stacked wellbore placement pattern, whereas Pad 2 is a 6-well pad with 3 target benches and a staggered wellbore placement pattern. Cuttings and produced oil samples were collected from both pads at every development bench, and geochemical DFHs and production allocations were estimated. The geochemical index from cuttings were in-line with the porosity log and wetness balance log collected while drilling. Based on the geochemical production allocation, both Pad 1 and Pad 2 showed vertical fracture growth was not constrained within the target bench. As a result, more vertical overlaps were detected which leads to a more severe vertical communication problem observed on Pad 1 where wellbores were vertically stacked above or below each other.\u0000 In this study, the geochemical fingerprinting result was used to calibrate microseismic events. The quantitative production allocation allowed us to filter out any non-effective events and realistically capture the productive stimulated rock volume for optimizing well spacing and landing depth. Last but not least, the geochemical production allocation was successfully integrated with other reservoir surveillance data such as interference well testing.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131175108","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":"Distributed Real-Time Multi-Pad Steam Allocation Optimization","authors":"Najmudeen Sibaweihi, J. Trivedi","doi":"10.2118/212757-ms","DOIUrl":"https://doi.org/10.2118/212757-ms","url":null,"abstract":"\u0000 In Steam-Assisted Gravity Drainage (SAGD) recovery, optimal real-time steam allocation from a shared steam generator to the physically coupled multi-pads can significantly improve long-term performance goals. However, multi-pad real-time optimization (RTO) with first-principle models can be computationally intensive. Furthermore, general-purpose optimization algorithms in RTO do not consider the future state beyond the prediction horizons to be optimized and treat the optimization problem as a long-term optimization process. Since steam is the primary cost factor in SAGD, Key Performance Indicators (KPI) such as Net Present Value (NPV), when used in RTO, result in low steam injection impeding steam chamber growth during the build-up and normal SAGD operational phase. Therefore, balancing steam chamber development and economics becomes essential for SAGD well-pads using RTO to meet long-term goals.\u0000 In this contribution, we implement the Alternating Direction Method of Multipliers (ADMM) and a dynamic data-driven model to reduce the computational cost of RTO. ADMM coordinates in real-time field-wide use of shared steam generation. The shared steam generation is a market commodity traded between the pads, with global coordination in real-time perturbation of their market prices. Four SAGD KPIs are implemented for a multi-pad RTO of the SAGD normal operations phase to see which KPI eventually grows the steam chamber without negatively affecting the long-term economic performance.\u0000 A SAGD field with four pads with 33 well-pairs shows that for all four pads, an economic-based KPI limits the achievement of long-term goals because it cannot account for the future state beyond the horizon under consideration due to hindered steam chamber growth. For the steam chamber expansion and bitumen recovery KPI, high recovery and economic performance are achieved, but with a high resource requirement, leading to a high carbon footprint. On the other hand, an alternating economic and bitumen recovery KPI achieves high economic performance while minimizing resource requirements that decrease carbon footprint.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"71 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132189368","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":"Investigation CO2 EOR Types with Constrained CO2 Volume and Impurities for a High-Quality Sandstone, Stratified Offshore Newfoundland Reservoir","authors":"Chau Quynh Pham, Ebeagbor Cleverson Esene, Anne Lesley James","doi":"10.2118/212811-ms","DOIUrl":"https://doi.org/10.2118/212811-ms","url":null,"abstract":"\u0000 The objective of this study is to evaluate the potential of CO2 sequestration coupled with oil recovery to lower the carbon intensity of incremental oil recovered considering different CO2 EOR types. A compositional stratified reservoir model (with/without crossflow) is used to investigate the effect of limited CO2 volume on the performance of CO2-WAG, enriched CO2-WAG, and carbonated water injection (CWI). We show that joint optimization of oil recovery and carbon storage can decrease carbon intensity. CO2 flooding, CO2-WAG, enriched CO2-WAG, and CWI are investigated under constrained CO2 volumes on a percentage pore volume basis. A sensitivity analysis using Response Surface Methodology (RSM) is carried out within a range of reservoir temperature (50-130°C) and pressure (20-70 MPa) conditions. CO2 volumes that can be captured from offshore power generation are likely insufficient for CO2 flooding but could work for CWI, CO2 WAG or enriched CO2 WAG (CH4-CO2 WAG). Highest incremental oil was found using CWI. However, it did not consider carbon pricing nor look to minimize oil production emissions intensity. Emissions intensity is the new metric during our transition to cleaner energy. CWI can store less than 20% amount of CO2 captured while CO2-WAG, enriched CO2-WAG with 7-10% lower oil recovery, however, can store much larger quantities. The stratified reservoir with crossflow cases had higher recovery factors and later water breakthrough than without crossflow cases. The use of WAG reduced the extent of crossflow and the high WAG ratio (3:1) would lead to a higher oil recovery (additional 3% for enriched CO2 WAG case). Recovery factor increased with decreased temperature and increased pressure, since CO2 is in its supercritical state in the range studied. Proxy models showed good performance with high determination coefficients (R2), between 0.93 - 0.99. EOR studies focus on incremental oil recovery (without carbon pricing). CCUS studies maximize CO2 storage (assuming infinite CO2). We investigate the value of capturing post combustion CO2 from offshore power generation considering constrained CO2 volumes and different EOR methods without reproducing CO2. This study investigates the joint optimization of oil recovery and carbon storage bringing a unique perspective and way to decrease carbon intensity during the oil transition era.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"67 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122815382","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":"An Experimental Study on the Effects of Competitive Adsorption During Huff-N-Puff Enhanced Gas Recovery","authors":"Jeremy Wolf, S. Maaref, S. Esmaeili, B. Tutolo, A. Kantzas","doi":"10.2118/212716-ms","DOIUrl":"https://doi.org/10.2118/212716-ms","url":null,"abstract":"\u0000 Gas is stored in tight reservoirs both as a free gas occupying the pores, and as an adsorbed gas on the rock matrix. Adsorbed gas exhibits liquid-like densities resulting in significantly more gas being stored on the rock surface. This research aims to highlight the effects of competitive adsorption during Huff-n-Puff enhanced gas recovery (EGR) on activated carbon to achieve maximum gas recovery. Pure methane was initially adsorbed by the activated carbon sample in four simple pure component adsorption stages. The methane was then produced in a primary production stage, allowing some methane to desorb from the activated carbon. The free and adsorbed methane was then displaced in five subsequent cyclical injection/production stages with a displacing gas, either nitrogen or carbon dioxide. The experiments were conducted at 30 °C, 45 °C, and 80 °C, and the temperature was maintained using a water bath. The purpose of testing a variety of temperatures was to highlight the effect of temperature on competitive adsorption and recovery factors. From the experiments, adsorption capacity was plotted as a function of the isothermal pressure and methane composition. This data was then fitted with the Extended Langmuir model because of its popularity and simplistic approach for multicomponent gas mixtures. It was observed that total adsorption capacity decreased as a function of temperature for both the nitrogen and carbon dioxide displacement experiments. Selectivity ratios were also determined for each experiment. At all temperatures, carbon dioxide had a higher selectivity ratio over methane compared to the selectivity ratio between nitrogen and methane. Selectivity ratios did not correlate with changing temperatures in both sets of experiments. Recovery factors were also determined for each experiment. Incremental recovery factors progressively decreased with each subsequent production stage. Cumulatively, the carbon dioxide experiments exhibited higher recovery at each temperature tested. For these experiments, irreversibilities were not considered due to the authors’ previous experience with single-component adsorption and desorption experiments on activated carbon [1]. To date, there have not been any EGR Huff-n-Puff experiments conducted on highly porous activated carbon samples with a primary focus on the effect of competitive adsorption. This research aims to highlight the effects of temperature and displacement gas type on the competitive adsorption between methane and nitrogen/carbon dioxide and its impact on the recovery factors. By doing so, EGR schemes can be better understood and modeled with improved inputs for competitive adsorption in each injection and production cycle. This will allow for more accurate production forecasting and help minimize the financial risk of costly EGR projects.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"69 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128617668","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 Sustainability Through the Utilization of Recycled Produced Water for Drilling Operations and the Associated Benefits","authors":"G. Heath, Dylan Hadley, T. Okesanya, D. Horton","doi":"10.2118/212814-ms","DOIUrl":"https://doi.org/10.2118/212814-ms","url":null,"abstract":"\u0000 In order to improve the global sustainability benchmarks of the drilling industry, there is a need to adopt more eco-friendly practices that will diminish the adverse environmental impact of drilling operations. Responsible energy development should prioritize environmental protection and sustainable practices, including the drilling fluid system selection.\u0000 An efficient environmental approach involves the recycling of produced water as a drilling fluid to combat its detrimental disposal requirements as well as reducing the usage of freshwater and potentially carcinogenic oil-based mud in drilling operations. While field data have shown that recycled production water can have superior performance and lower costs, the widespread utilization of produced water has experienced slow adoption due to its unique set of challenges. These challenges include variability in ionic composition, increased corrosion, and scaling potential, along with health and safety considerations, which reduce its overall desirability. These factors are further compounded by a general lack of technical knowledge around water chemistry dynamics, treatment, and system management. There is a need for a \"playbook\" that demystifies the technical complexities of produced water, thereby bridging a crucial gap in the drilling fluids literature and accelerating the adoption of this lower environmental footprint fluid.\u0000 This paper presents a comprehensive overview and pragmatic insight into the usage of produced water for drilling operations from real-life case studies in Western Canada. This paper is designed as an aid to understand the associated screening, testing, treatment, and practical pitfalls of using production water as a drilling fluid, which is illustrated with real-life data. The aim is to encourage and accelerate the adoption of production water as a sustainable source of superior drilling fluid systems by more operators and drilling fluid service providers. Consequently, improving the environmental sustainability of the drilling industry.","PeriodicalId":437231,"journal":{"name":"Day 1 Wed, March 15, 2023","volume":"38-40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116769143","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}