Mohamed El Sgher, K. Aminian, Dalal Aldbayan, A. Sattari, S. Ameri
{"title":"The Impact of Formation and Fracture Properties Alterations on the Productivity of the Multi-Stage Fractured Marcellus Shale Horizontal Wells","authors":"Mohamed El Sgher, K. Aminian, Dalal Aldbayan, A. Sattari, S. Ameri","doi":"10.2118/211892-ms","DOIUrl":"https://doi.org/10.2118/211892-ms","url":null,"abstract":"\u0000 As the reservoir deplete, the pore pressure decreases and the effective stress increases. The increase in the effective stress results in the formation compaction which can alter the formation and hydraulic fracture properties. This is particularly significant for a Marcellus shale horizontal well with multi-stage hydraulic fracture due to low Young's modulus and moderate Poisson's ratio of the Marcellus shale. The degree of effective stress increase depends on the initial productivity of the well, which is influenced by the hydraulic fracture properties, stage spacing, as well as the operating conditions. It is therefore necessary to couple the geomechanical and fluid flow simulations to accurately predict the gas production from a horizontal Marcellus Shale well with multi-stage fractures. The objective of this study was to investigate the impact of the formation mechanical properties (Young's modulus and Poisson's ratio), the hydraulic fracture properties (length, initial conductivity, spacing), as well as operating conditions (wellbore pressure) on the productivity of a horizontal Marcellus Shale well with multi-stage fractures.\u0000 The advanced technical information available from the Marcellus Shale horizontal wells located at the Marcellus Shale Energy and Environment Laboratory (MSEEL) site provided an opportunity to investigate the impact of the shale compressibility on gas production. The core, well log, well test, completion, stimulation, and production data from the wells at MSEEL site were utilized to estimate the shale mechanical and petrophysical properties as well as the hydraulic fracture characteristics. The results of the data analysis were then utilized to develop a reservoir model for a horizontal well completed in Marcellus Shale with multi-stage hydraulic fractures. A geomechanical (Mohr-Coulomb) module was coupled with reservoir model to determine the effective stress distribution and the formation compaction and its impact on the shale porosity. The impact of the shale compaction on the permeability (for both matrix and fissure) and the conductivity of the hydraulic fractures were determine from the Marcellus shale core plug analysis as well as the published measurements on the propped fracture conductivity in Marcellus shale and were incorporated in the reservoir model.\u0000 The inclusion of the compressibility impacts in the reservoir model provided a more realistic simulated production profile. The gas recovery was found to be negatively impacted by the formation compaction due to the increase in the effective stress. The reduction in the conductivity of the hydraulic fractures due to the compressibility impact was found to have the most adverse effect on the gas recovery. The compressibility impacts were found to be more severe during the early production due to higher production rates. Finally, the model was employed to investigate the impact of the formation mechanical properties, hydraulic fracture properties, and the o","PeriodicalId":407915,"journal":{"name":"Day 2 Wed, October 19, 2022","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122451083","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 Transport Analysis of the Anionic High Viscosity Friction Reducer in High-TDS Marcellus Shale Formation Water Environments","authors":"Xiaojing Ge, Ghith Biheri, Abdulmohsin Imqam","doi":"10.2118/211884-ms","DOIUrl":"https://doi.org/10.2118/211884-ms","url":null,"abstract":"\u0000 High viscosity friction reducers (HVFRs) have been recently gaining more attention and increasing in use, not only as friction-reducing agents but also as proppant carriers. Reusing of produced water has also been driven by both environmental and economic benefits. In Marcellus Shale regions, slickwater fracturing fluids are commonly used, which reduce the number of fluid additives required and foster high retained conductivity but require high water volumes and pumping rate. In contrast, HVFRs can also exhibit high retained conductivity with less water and horsepower required and much more other operational and economical advantages. Currently, most friction reducers on the market are anionic friction reducers, which are fully compatible with most produced water with low to medium level of Total Dissolved Solids (TDS) but show significant decreasing at high TDS conditions in term of their friction reduction performance in most cases. Concerns remain about performances of using anionic HVFRs with produced water to transport proppant. The ultimate objective of this experimental study is to investigate whether increasing loading of the anionic HVFR can compensate the side effects of high TDS and temperature in Marcellus Shale formation. Anionic HVFRs at 4, 6, and 8 gallons per thousand gallons (GPT) were selected and analyzed. The rheology measurement of different concentrations of anionic HVFRs were conducted with deionized (DI) water, high TDS Marcellus Shale formation water, and 30,000 mg/L NaCl solution at temperature of 60 °C. Static and dynamic proppant settling tests were conducted with various HVFR concentrations at high TDS and temperature conditions. The results showed that high TDS and temperature decreased the viscous and elastic profiles of the anionic HVFR. In particular, the elastic profile became negligible. Differences between monovalent and divalent cations effects on the rheology properties and proppant transport capability of the anionic HVFR were also negligible at high TDS and temperature conditions. Increasing loading of the anionic HVFR had very limited effects on improving its rheology properties and further proppant transport capabilities at Marcellus Shale formation conditions. Therefore, future study can be focused on modifying proppant, such as sizes and concentrations, and slurry injection rate to get better fracturing results in Marcellus Shale formation.","PeriodicalId":407915,"journal":{"name":"Day 2 Wed, October 19, 2022","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128473546","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}
Andrea Cristina Lopez, Carlos Pedro Rodolfo Orlandi, Maria Eugenia Salamanca, Luis Sebastian Perri, M. Volkov
{"title":"Spectral Acoustic Logging to Guide the Successful Remediation of Gas Well. Case Study","authors":"Andrea Cristina Lopez, Carlos Pedro Rodolfo Orlandi, Maria Eugenia Salamanca, Luis Sebastian Perri, M. Volkov","doi":"10.2118/211866-ms","DOIUrl":"https://doi.org/10.2118/211866-ms","url":null,"abstract":"\u0000 The case study presented describes how successive leak detection logging surveys defined, first the remedial workover plan, and subsequently evaluated the results of the different cementing stages in the workover operation, in a well with gas bubbling at surface.\u0000 The subject well evidenced gas bubbling in the cellar, right behind the conductor. None of the annuli exhibited sustained pressure. Therefore, the source and path of the leak was unknown. A tool string including passive spectral acoustic and high precision temperature modules was utilised to define both the source and path of the leak. This diagnostics was performed for remedial workover planning. Subsequently, during the remedial workover, additional logging surveys were utilised to evaluate the isolation operations.\u0000 As a result, all reservoir contributing zones were located and the leak path was defined. This information enabled a targeted workover plan pinpointing the most suitable zones for cementing stages, which also included three confirmation surveys at the end of each cementing stage to evaluate the isolation achieved. The first two surveys indicated the success of cementing operations. After the completion of all cementing stages, before the last logging run, gas bubbling at surface re-started. The final survey evidenced an acoustic response compatible with the flow of residual gas trapped behind the casing, which was deemed as the possible cause of this bubbling. This scenario of flow of residual gas was confirmed after one month, when gas bubbling at surface ceased, which proved the success of the workover operation.\u0000 This diagnostics, conveyed through tubing in a well filled with gas, allowed for the identification of the source and path of a leak taking place entirely behind casing strings, with no communication with the wellbore. It enabled an effective and efficient remedial workover, allowing for targeted workover planning, as well as online evaluation of remedial operations for decision making, which ultimately led to workover objectives being successfully achieved at minimum cost and time.","PeriodicalId":407915,"journal":{"name":"Day 2 Wed, October 19, 2022","volume":"128 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116156350","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":"Two Superior Shale Oil Enhanced Recovery Methods for the Utica Shale","authors":"R. Downey, K. Venepalli, J. Erdle","doi":"10.2118/211887-ms","DOIUrl":"https://doi.org/10.2118/211887-ms","url":null,"abstract":"\u0000 The Utica Shale is a very large, important oil and gas resource in the eastern United States. While gas production dominates, oil production from horizontal shale oil wells in the Utica has grown from 15 BOPD in June 2011 to a peak of 50,000 BOPD in September, 2019 with 2,485 horizontal shale oil wells in production. The Utica shale dips to the east, shallow in east-central Ohio to deep in western Pennsylvania. Likewise, hydrocarbons in the Utica trend from light oil with low GOR in eastern Ohio to dry gas in western Pennsylvania. Liquid hydrocarbons are produced from the shale via solution gas drive. The shallow, black oil area of the play has to date been noncommercial. A recent enhanced oil recovery test in the shallow black oil area of the Utica has provided encouraging results. Our objective is to introduce two novel EOR processes that can greatly increase the production and recovery of oil and gas from the Utica shale, while reducing the cost per barrel of recovered oil, and reducing GHG emissions and water consumption/production/disposal.\u0000 Two superior shale oil EOR methods are proposed that utilize a triplex pump to inject a solvent liquid into the shale oil reservoir, and an efficient method to recover the injectant at the surface, for storage and reinjection. One of the methods also incorporates the application of rock mechanics to further enhance oil and gas recovery. The processes are designed and integrated during operation using compositional reservoir simulation in order to optimize oil recovery.\u0000 Compositional simulation model of a Utica shale horizontal well producing rich gas condensate was conducted to obtain a history match on oil, gas, and water production. The matched model was then utilized to evaluate two novel shale oil EOR methods under a variety of operating conditions. The modeling indicates that for this particular well, incremental oil production of 500% over primary EUR may be achieved in the first five years of EOR operation via the SuperEOR method. A further enhanced EOR method, UltraEOR, is shown to potentially increase oil recovery by 850% in the first five years of EOR operation, and as much as 1100% after 12 years. These methods, which are patent-pending, have numerous advantages over cyclic gas injection, such as much greater oil recovery, much better economics/lower cost per barrel, reduced gas containment issues, use of far less horsepower and fuel, shorter injection time, longer production time, smaller injection volumes, scalability, faster implementation, precludes the need for artificial lift, elimination of the need to buy and sell injectant during each cycle, ability to optimize each cycle by integration with compositional reservoir simulation modeling, and lower emissions.\u0000 These superior shale oil EOR methods have been modeled in seven major US shale oil plays, indicating large incremental oil recovery potential. Core tests have confirmed the SuperEOR modeling results and demonstrated high oil rec","PeriodicalId":407915,"journal":{"name":"Day 2 Wed, October 19, 2022","volume":"60 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130445502","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}
Amanda Parrish, A. Sattari, Mohamed El Sgher, K. Aminian, S. Ameri
{"title":"Application of the Rate Transient Analysis for Estimation of the Stimulated Reservoir Volume Associated with a Marcellus Shale Horizontal Well","authors":"Amanda Parrish, A. Sattari, Mohamed El Sgher, K. Aminian, S. Ameri","doi":"10.2118/211871-ms","DOIUrl":"https://doi.org/10.2118/211871-ms","url":null,"abstract":"\u0000 the Flowing Material Balance (FMB) has become popular in recent years because it does not require static (shut-in) pressure data that are needed for the traditional material balance application. This method is particularly useful for the shale reservoirs where shut-in pressure data are rarely available. The application FMB to the shale reservoirs is challenging because of the presence of the adsorbed gas, due to high organic content, and the long time that is required to establish boundary-dominated flow (BDF) due to ultra-low permeability. However, the interference between the fracture stages in a horizontal well with multiple hydraulic fracture stages leads to an early BDF period during the production. Therefore, the production data from this early BDF period can be utilized to determine the gas in place which can be attributed to the stimulated reservoir volume (SRV) and is of more economic significance.\u0000 The objective of this study was to investigate the applicability of the FMB for estimation of the gas in the SRV associated with a Marcellus shale horizontal well with multiple hydraulic fracture stages. The available information from several existing horizontal wells at MSEEL site in West Virginia were utilized to develop a reservoir for model for a Marcellus shale horizontal well with multiple hydraulic fracture stages. To accurately simulate the production data, the adsorbed gas as wells as geomechanical factors, derived from the laboratory and published data, were incorporated in the model. The geomechanical factors account for the impairments in hydraulic fracture conductivity and the reduction in the formation (matrix and fissure) permeability caused by the reservoir depletion. The simulated production data were then analyzed by both conventional method and King method which accounts for gas desorption.\u0000 The FMB method which accounts for gas desorption was found to provides reliable estimates of the gas in place in SRV. The analysis of the production data indicated the presence of two BDF. The analysis of the data from the early BDF provided the gas in place in SRV. The analysis of the data from the late BDF provided the total gas in the reservoir. The results were found to be comparable to the values determined from the model. Therefore, the reliability of the data analysis method was confirmed.","PeriodicalId":407915,"journal":{"name":"Day 2 Wed, October 19, 2022","volume":"2007 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125618439","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}