Day 1 Mon, October 03, 2022最新文献

{"title":"Bioremediation Study on Formation Damage Caused by Hydraulic Fracturing: A Microfluidic Approach","authors":"Songyuan Liu, Chao-yu Sie, Fatee Malekahmadi, Bo Lu, Yifan Li, Cara Fan, Xinyue Zhang, O. Serediak, Jelayne Fortin, A. Abedini","doi":"10.2118/210089-ms","DOIUrl":"https://doi.org/10.2118/210089-ms","url":null,"abstract":"\u0000 Hydraulic fracturing has been applied to unconventional reservoirs with low permeability to achieve higher productivity and economic potential. However, polyacrylamide-based friction reducer and guar gum, two of the most common components in fracturing fluid could cause formation damage by penetrating into the matrix and blocking the flow path. To regain the conductivity of the damaged area, a bioremediation method was developed and validated by a microfluidic approach. Modified nutrients were used to stimulate the indigenous bacteria that could consume or break the polymer residues.\u0000 Indigenous bacteria were extracted from oil field produced water collected with customized anaerobic sampling kits which have been sterilized. Feasibility studies were conducted to investigate the indigenous bacteria activity with and without nutrient supply. Fracturing fluid, field water, and a modified nutrient recipe which contained 300 ppm of inorganic salts were loaded into anaerobic sample vials in a 140°F - 150°F incubator. Microfluidic tests were performed in 150°F oven with microfluidic chips designed and fabricated based on the topology of matrix networks. Fracturing fluids were injected into a chip saturated with field water to simulate formation damage. Remediation fluid consisting produced water, injection water and nutrient was injected into the chip. After two weeks soaking, 2% KCl brine was then injected into the chip at 200 nl/min until a stable pressure drop was achieved. Microscopic pictures were taken before and after soaking to demonstrate the polymer damage and the remediation of microfluidic chips.\u0000 The indigenous bacteria were successfully stimulated with and without the existence of the friction reducer based on the results of feasibility tests. Microfluidic tests showed there is a significant difference in precipitations between the case with and without nutrient supply, which indicates that the bioremediation method could regain conductivity of the damaged formation.\u0000 This work is novel research on bioremediation application in unconventional reservoirs with only indigenous bacteria involved. The customized sampling technology and laboratory approach could prevent contamination of other microbes and oxygen, which could improve the quality of the research. Microfluidic chip is a great simulation of porous media and a proof of concept between scientific hypothesis and field application which requires small sample size and provides good reproducibility. In field applications, only an extremely low amount of nutrient is required in this process which provide great economic potential. Additionally, the injected nutrients will be fully consumed by the bacteria which makes this technology is an Environmental, Social and Governance (ESG) approach in energy industry.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129398318","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":"Production Technology R&D: Insights from Upstream Research","authors":"S. Al-Mutairi, M. AlTammar","doi":"10.2118/210442-ms","DOIUrl":"https://doi.org/10.2118/210442-ms","url":null,"abstract":"\u0000 Worldwide, research and development (R&D) programs have long been an integral part of most oil and gas companies. Large and small oil companies alike continuously perform several R&D activities on some level to improve their operations and services. With the advent of technology in recent years, companies are increasingly recognizing the competitive advantage that R&D provides to their core businesses. In this paper, we share insights from over a decade of R&D experience by the Production Technology Division (PTD) within Saudi Aramco's EXPEC Advanced Research Center (EXPEC ARC). The team has pioneered many technologies that significantly enhanced production operations, and helped in reducing operations’ carbon footprint in oil and gas fields. We highlight how the research team grew over time, and how they interacted and engaged with field proponents in their R&D work while providing several illustrative examples. We also discuss the focus and strategy of the team going forward.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115812191","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":"Impacts of Carbonated Brine-Rock Reactions on Multiphase Flow Properties in Upper Minnelusa Sandstone: Implication for CO2 Storage","authors":"Zuhao Kou","doi":"10.2118/212389-stu","DOIUrl":"https://doi.org/10.2118/212389-stu","url":null,"abstract":"\u0000 The impact of carbonated brine-rock geochemical reactions on porosity, permeability, and multiphase flow responses is relevant to the determination of CO2 storage capacity of deep saline aquifers. In this research, carbonated brine flooding experiments were performed on core samples consisting of poorly sorted, quartz-rich sand with laminated bedding from a target CO2 storage formation in Wyoming. Complementary pre- and post-injection lab measurements were performed. Results showed that both core porosity and permeability increased after a seven-day carbonated brine injection, from 6.2% to 8.4% and 1.6mD to 3.7mD, respectively. These changes were attributed to carbonate mineral dissolution, which was evidenced by the effluent brine geochemistry, pore-throat size distribution and surface area. To be more specific, within the more permeable section of core samples, containing larger pore size, the permeability increment is apparent due to dolomite mineral grains and cements dissolution. However, for the lower permeability section, corresponding to the smaller pore size, mineral precipitation possibly lessened dissolution effects, leading to insignificant petrophysical properties changes. Consequently, the observed heterogeneous carbonated brine-rock interactions resulted in changes of CO2/brine relative permeability. This research provides a fundamental understanding regarding impacts of fluid-rock reactions on changes in multiphase flow properties of eolian sandstones, which lays the foundation for more accurate prediction/simulation of CO2 injection into deep saline aquifers.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"430 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131363788","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":"Iron Sulfide Scale Inhibition Through Adsorption of Chelating Agents","authors":"Nijat Gasimli, M. Mahmoud, Amjed Hassan, Muhammed Shahzad Kamal, S. Patil, Ridha Al-Abdrabalnabi","doi":"10.2118/210275-ms","DOIUrl":"https://doi.org/10.2118/210275-ms","url":null,"abstract":"\u0000 An important oilfield issue is the formation of a wide range of scales during oil and gas well operations. Oilfield scales hinder assessing an optimum hydrocarbon production as their precipitation on formation, various surface, and downhole equipment leads to many problems, including pressure decrement, formation damage, and operational failure of subsurface equipment. One type of these scales is the iron sulfide scale and based on studies in the Khuff reservoir, iron sulfide scales are likely to deposit on production tubing and rock formation. Therefore, it becomes essential to restrain the occurrence of iron sulfide scale using environmentally friendly chemicals in production tubing, water injection wells, and near-wellbore formation.\u0000 The primary focus of this work is the prevention of iron sulfide scale deposition in carbonate formations during water injection applications. Iron sulfide scale inhibition was studied through dynamic inhibition adsorption experiments. In contrast to conventional experiments, for scale inhibition and adsorption of chelating agents (static bottle, dynamic filter tube tests) and simulation studies, a novel experimental setup (coreflooding experiments) was proposed to study the inhibitor adsorption. Broad concentrations of high-pH aminocarboxylic acids (such as ethylenediaminetetraacetic acid (ETDA) and diethylenetriamine pentaacetate acid (DTPA)) were examined (10 wt%, 15 wt%, and 20 wt%), at temperatures of 120°F and 200°F.\u0000 Results of the study revealed that iron (III) precipitation is an obvious threat causing severe formation damage in carbonate rocks by significantly decreasing the rock permeability. Adsorption of chelating agents on limestone rocks highly depends on their concentrations. Specifically, an increase in the concentration of EDTA and DTPA at elevated temperature conditions resulted in higher adsorption. The inhibition experiments revealed that 20 wt% EDTA could significantly decrease the iron sulfide scale precipitation.\u0000 Unlike the conventional testing methods for scale formation and prevention, a novel experimental setup - coreflooding during the inhibitor adsorption, formation, and inhibition of iron sulfide scale in carbonate formation was used. The main advantage of the method is the consideration of permeability alteration happening due to the scale formation. Another point is that in previous studies, various scale control chemicals and experimental approaches have been suggested for iron sulfide scale inhibition, and polymeric, phosphonate, and sulfonated co-polymeric inhibitors were used. However, the subgroup of chelating agents - aminocarboxylic acids, was used in this study.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131642337","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":"Operator Successfully Trials Novel Cementing Technologies in a Deepwater Gulf of Mexico Exploration Well","authors":"Tyler R. Reynolds, M. M. M. Abdullah, J. Bowling, S. Chandrasekhar, M. R. Paimin, A. Z. A. Redzuan, M. Z. Mohiyaddin","doi":"10.2118/209994-ms","DOIUrl":"https://doi.org/10.2118/209994-ms","url":null,"abstract":"\u0000 The objective of this paper is to present the planning, simulations, laboratory testing and operational results for the initial deepwater deployment of a new cementing technique which utilizes a \"heat sweep\" of warm seawater circulated inside the casing after cement placement to accelerate early compressive strength development. This technique is made possible through a novel stabbed-in inner string cementing technology which also reduces operational risk for the cement job and saves rig time by eliminating conventional cement shoe tracks.\u0000 The pre-project planning included comprehensive thermal simulations for placement of the \"heat sweep\", the 22″ surface casing cement job's temperature profile over time and the corresponding effect on compressive strength development. Additional laboratory testing of the \"rig-blend\" cement to be used in the well was also completed with and without the effect of the \"heat sweep\" to finalize the wait-on-cement (WOC) criteria for the 22″ cement job. Finally, a set of detailed operational steps were formalized in the drilling program.\u0000 The 1000 m (3281 ft) 22″ surface casing cement job at 1532 m (5026 ft) water depth was successful, and several best practices and lessons learned were recorded for the deployment of the new technologies.\u0000 Highlights included preparing the \"heat sweep\" utilizing rig systems to the initial placement temperature of 75°C (167°F), cementing through the stabbed-in inner string system, placement of the \"heat sweep\" inside the casing, and recovering a downhole cement sample and temperature logger from the bottom-hole assembly (BHA).\u0000 The downhole temperature logger recorded that a maximum 37.07°C (98.72°F) was delivered to the casing shoe, which was roughly double the maximum recorded environmental temperature and an exponential increase above the minimum environmental temperature, near freezing, at the mudline.\u0000 The \"heat sweep\" generated approximately 9 times more compressive strength in the cement over 8 hours (1150.55 psi) when compared to the base case without the \"heat sweep\" effect (129.81 psi). This increase in compressive strength development was equivalent to a 4-hour WOC reduction to develop 100 psi in the tail slurry or a 16-hour reduction in WOC to develop 500 psi in the lead slurry near mudline.\u0000 Additionally, the 22″ casing pressure tested to 2000 psi, and the shoe was drilled out in less than 20 minutes, saving 6 1/2 hours of rig time when compared to the Operator's most recent subsea well. The formation integrity test (FIT) achieved a slightly higher pressure than expected, and the subsequent 17 ½\" section was drilled in a single fast run.\u0000 The subject novel cementing technologies have the potential to reduce costs and drive efficiency for deepwater drilling operations. This case study presents the first deepwater application for utilizing heated seawater to help rapidly build compressive strength in a cement job after placement through a novel stabbed-in inner string cem","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134218772","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":"Electro-Hydraulic Servo Actuation for Well Completions","authors":"D. M. Lerner, Andre E. Orban","doi":"10.2118/210069-ms","DOIUrl":"https://doi.org/10.2118/210069-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Well Completions are challenged with the demands of managing increased multiple production zones.\u0000 This paper addresses a solution to these issues:\u0000 Reduce the number of hydraulic control lines.\u0000 Provide independent production zone flow control.\u0000 Support a multiplicity of hydraulic actuated devices.\u0000 \u0000 \u0000 \u0000 These Well Completion challenges are addressed using networked Electro-hydraulic Servo Actuators (EHSA). The EHSA is a small diameter, closed loop, hydrostatically balanced electro-hydraulic actuation system. EHSA has a feature set to support intelligent and autonomous multizone Well Completions. Each EHSA servo provides controlled operation of a device at a remote endpoint downhole.\u0000 Bidirectional flow is obtained directly from the rotation of the pump and motor, eliminating the use of check, relief, and solenoid valving. Measured flow and pressure provide incremental precision positioning.\u0000 Multiple hydraulic control lines are eliminated.\u0000 \u0000 \u0000 \u0000 Years of extensive testing programs validated reliable and consistent operations verified in hydrostatic autoclave stress test equipment. EHSA tests demonstrate years of operation, estimated to meet or exceed 20 years of operation.\u0000 The system operates with electrical wires providing direct command/response capability and power. A single TEC line can support a multiple EHSA network.\u0000 Alternately, pressure pulse commands can be transmitted from the surface to control each battery powered EHSA. Autonomous control in response to sensor inputs allows for adjustment of the well control devices, for instance in response to well pressure changes. A real-time clock provides for a predetermined schedule of operations, possibly combined with\u0000 command/response, autonomous control, and sensor measurements.\u0000 Self-balancing eliminates hydraulic lock by uniquely adding or disposing of fluid imbalance with the hydraulic reservoir. The positive displacement operation is calibratable and proven highly repeatable.\u0000 Remedial override is inherent in the EHSA because there are no valves.\u0000 \u0000 \u0000 \u0000 The EHSA is a multiple-use hydraulic engine with intelligent control features for various types of completion devices either single-use or permanent installation.\u0000","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127771828","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":"Experimental Investigation of Hydraulic Fracturing on the Montney Formation","authors":"R. Safari, R. Albert, D. Laycock","doi":"10.2118/210017-ms","DOIUrl":"https://doi.org/10.2118/210017-ms","url":null,"abstract":"\u0000 To assist in understanding the role of rock fabric, stress state, and fracturing fluid viscosity on fracture geometry, four large, dry blocks (28\" × 28\" × 36\") sourced from a Montney formation outcrop were hydraulically fractured in a series of laboratory experiments. These tests investigated the role of texture on hydraulic fracture (HF) propagation with different fluid viscosities, and strike-slip and normal stress regimes. Each block was hydraulically fractured in two stages to allow comparison, within the same overall rock fabric, of fractures created by the different viscosities and injection rates. Pre-existing discontinuities, including calcite-cemented fractures and calcite layers were mapped prior to the test by a goniometer. The static elastic properties, failure parameters, dynamic properties, and fracture toughness of the host rock were measured in detail. During each test, the HF propagation was monitored by recording the generated acoustic emissions. Subsequently, the blocks were carefully dissected, and HF geometries were mapped in detail by laser profilometry.\u0000 The results showed that heterogeneity in the rock texture and its location had a primary effect on the fracture propagation. The direction of the maximum stress played, at best, a secondary role. The fracture dynamics determined with acoustic emissions indicated a relatively symmetric, pancake-like shape with high dimensionless viscosity and more asymmetry with low viscosity fluid. Visual inspection of the resulting fractures showed truncated elliptical shapes with both viscosities and with the higher viscosity having less containment. Acoustic emissions clearly indicated HF initiation, propagation, and interaction with the rock fabric, indicating arrest and spreading along pre-existing interfaces in cases of low dimensionless viscosity, and more uniform propagation in cases of high viscosity but with the rock fabric having a significantly reduced impact.\u0000 The experiments demonstrated the likelihood of the substantial impediment to successful proppant delivery and hydrocarbon production in the field based on observed occurrences of HF arrest on pre- existing interfaces (indicating possible height containment) as well as the formation of branches and step- overs. Our results indicated that sufficient knowledge of the fabric, in conjunction with proper selection of injection fluid and rates, may provide additional height containment and hence enhance lateral fracture extension and improve the depletion of the pay zone. Ultimately, optimum production may more likely be achieved with collection of further rock samples, laboratory testing, and modeling of pre-existing interfaces to allow relative ranking of these barriers.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115390120","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":"Transient Analysis of Sandface and Wellbore Temperature in Naturally Fractured Geothermal Reservoirs: Numerical and Analytical Approaches","authors":"Cao Wei, Shiqing Cheng, Dengke Shi, Dawei Liu, Xiuwei Liu, Ruilian Gao, Yang Wang, Haiyang Yu","doi":"10.2118/209962-ms","DOIUrl":"https://doi.org/10.2118/209962-ms","url":null,"abstract":"\u0000 This work presents the numerical and analytical temperature solutions that couple the transient reservoir/wellbore thermal models to analyze the temperature measurements recorded at producing horizon or at a certain gauge depth above it for estimating the physical and thermal properties of naturally fractured geothermal reservoir (NFGR) during drawdown and buildup periods. The NFGR is replicated by a more general triple-porosity system adopted from Abdassah and Ershaghi model. We first develop numerical and analytical solutions to predict the sandface temperature in NFGRs, accounting for the Joule-Thomson (J-T) effect, adiabatic heat expansion/compression effect, heat convection and conduction. The developed numerical solution is verified and found to agree with the proposed analytical solutions. Then, the wellbore heat flow model adopted from Hasan and Kabir model is coupled with NFGR model to predict the wellbore temperature at a certain gauge depth above producing horizon.\u0000 The results show that three heat radial flow regimes and two thermal inter-porosity regimes have been identified. It is demonstrated that the early-time heat flow is dominated by the adiabatic heat expansion/compression effect, and the intermediate- and late-time heat flows are dominated by J-T heating/cooling effect. It is demonstrated that thermal properties such as J-T coefficient, adiabatic heat expansion coefficient and fracture intrinsic porosity can be estimated through temperature transient analysis, which are not accessible by pressure data. The results also show that when the gauge location is near the producing horizon, the heat transfer regimes keep almost identical to sandface during drawdown period. As the distance between the gauge location and producing horizon increases, drawdown-wellbore temperatures are more dominated by wellbore heat loss, thereby may miss some information contents from reservoir. Moreover, buildup-wellbore temperatures are usually dominated by wellbore heat loss and do not exhibit any discernable flow regimes even though gauge location is near the producing horizon. It is demonstrated that wellbore temperature derivative exhibits unit slope at early times for drawdown and buildup periods. Finally, we develop an integrated semilog-straight-line analysis workflow of combining sandface pressure and temperature data to estimate NFGR properties. Synthetic test example is interpreted to demonstrate the applicability of the developed workflow.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116345202","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":"Wettability Alteration of Kerogen by Interacting with Hydraulic Fracturing Fluid","authors":"X. Yi, K. Lee","doi":"10.2118/210246-ms","DOIUrl":"https://doi.org/10.2118/210246-ms","url":null,"abstract":"\u0000 The recent increase in unconventional oil and gas exploration and production has promoted active research on hydraulic fracturing, but the impact of interactions between fracturing fluid and kerogen on the alteration of kerogen wettability has not been well understood. The objective of this study is to experimentally estimate the changing wettability of kerogen with various thermal maturity levels by the interactions with hydraulic fracturing fluid.\u0000 To achieve the objective, kerogen was isolated from a bulk rock of organic-rich shale with different types and maturities. Kerogen isolates was kept in a mix with synthetic hydraulic fracturing fluid under the temperature of 80 °C for 14 days. Relative changes of sulfate ions were analyzed by using Ion Chromatography (IC). In the measurement of kerogen wettability, sessile drop method was applied to measure the direct contact angle by utilizing the Drop Shape Analyzer (DSA). During the reaction with hydraulic fracturing fluid, kerogen isolates were analyzed by conducting functional group analysis, which provided the supplemental information on the wettability of kerogen. Functional groups of kerogen were analyzed by using the Attenuated Total Reflectance Fourier-Transform Infrared spectroscopy (ATR-FTIR).\u0000 The reaction of fracturing fluid and kerogen isolates from various organic-rich shales were conducted, and it is experimentally demonstrated that the interactions between kerogen and fracturing fluid would cause substantial wettability alterations in organic pores and fractures that depend on the types and maturities of kerogen. The DSA results indicated that the air/water-contact angle decreases after the reaction, regardless of the types and maturities of kerogen, while the higher level of maturity of kerogen led to a greater change of air/water-contact angle. The results of ATR-FTIR showed that the hydrophobic functional groups were lost in the mature kerogen isolates, and they were potentially lost in the relatively lower level of maturity-kerogen isolates due to the oxidation, indicating that the kerogen showed increasing hydrophilicity, which provided a strong support to the DSA results.\u0000 This study experimentally determined the wettability alteration of kerogen by interacting with organic additives in hydraulic fracturing fluid. The results of this investigation will provide a significant step forward in evaluating the multiphase fluid transport in organic-rich shales with the wettability alteration and resulting hydrocarbon production.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"72 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128654744","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":"Microwave-Assisted Catalytic Heating for Enhanced Clean Hydrogen Generation from Methane Cracking in Shale Rocks","authors":"K. Yan, Q. Yuan, Xiangyu Jie, Xiaoqiang Li, J. Horita, Jacob Stephens","doi":"10.2118/210292-ms","DOIUrl":"https://doi.org/10.2118/210292-ms","url":null,"abstract":"\u0000 Steam methane reforming (SMR) technology generates about 95% hydrogen (H2) in the United States using natural gas as a main feedstock. While hydrogen is clean, the process of hydrogen generation via SMR is not, as it emits about 10 times more carbon dioxide (CO2) than hydrogen. The CO2 has to be captured and sequestrated in reservoirs or aquifer systems, which is costly. A revolutionary approach is to generate and extract hydrogen directly from petroleum reservoirs by taking advantage of the abundant unrecovered hydrocarbons in reservoirs. This approach does not involve natural gas production, transportation, or refinery. Meanwhile, the CO2, if generated, will be sequestrated simultaneously in reservoirs without being produced to surface. This approach is therefore potentially low cost and environmentally friendly. In this paper, we propose to use microwave-assisted catalytic heating to enhance methane conversion to hydrogen within shale gas reservoirs. To validate this concept, we conducted a series of experiments to crack methane streams flowing through shale rock samples and powders in a microwave reactor. With silicon carbide (SiC) as the microwave receptor, the temperature of shale samples can quickly reach to above 700 °. The methane conversion efficiency is up to 40.5% and 100% in the presence of Fe and Fe3O4 catalysts at the measured temperature of 500° and 600 °, respectively. Interestingly, the presence of shale is favorable for methane cracking at a relatively lower temperature compared to the case with the same weight percentage of SiO2 in heated samples. The thermal decomposition of carbonate in shale rocks also benefits the improvement of permeability of shale. The influences of different shale weight ratios and methane flow rates are also investigated.","PeriodicalId":223474,"journal":{"name":"Day 1 Mon, October 03, 2022","volume":"101 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129591728","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}