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Article(id=1236679388700406753, tenantId=1146029695717560320, journalId=1210938733613449225, issueId=1236679384321544791, articleNumber=null, orderNo=null, doi=10.19666/j.rlfd.202405131, pmid=null, cstr=null, oa=null, hot=null, price=null, onlineType=0, articleFormat=0, articleType=null, articleTypeStr=null, receivedDate=1715788800000, receivedDateStr=2024-05-16, revisedDate=null, revisedDateStr=null, acceptedDate=null, acceptedDateStr=null, onlineDate=1772776942658, onlineDateStr=2026-03-06, pubDate=1735056000000, pubDateStr=2024-12-25, doiRegisterDate=null, doiRegisterDateStr=null, onlineIssueDate=1772776942658, onlineIssueDateStr=2026-03-06, onlineJustAcceptDate=null, onlineJustAcceptDateStr=null, onlineFirstDate=null, onlineFirstDateStr=null, sourceXml=null, magXml=null, createTime=1772776942658, creator=13701087609, updateTime=1772776942658, updator=13701087609, issue=Issue{id=1236679384321544791, tenantId=1146029695717560320, journalId=1210938733613449225, year='2024', volume='53', issue='12', pageStart='1', pageEnd='160', issueExtLink='null', onlineDate='null', pubDate='null', beforeIssueId=null, nextIssueId=null, price=null, status=1, issueComplete=1, articleOrder=1, issueType=-1, specialIssue=null, createTime=1772776941614, creator=13701087609, updateTime=1772777031740, updator=13701087609, preIssue=null, nextIssue=null, ext={EN=IssueExt(id=1236679762404504298, tenantId=1146029695717560320, journalId=1210938733613449225, issueId=1236679384321544791, language=EN, specialIssueTitle=, coverIllustrator=null, specialIssueEditor=, specialIssueAbout=), CN=IssueExt(id=1236679762404504299, tenantId=1146029695717560320, journalId=1210938733613449225, issueId=1236679384321544791, language=CN, specialIssueTitle=, coverIllustrator=null, specialIssueEditor=, specialIssueAbout=)}, issueFiles=null}, startPage=10, endPage=20, ext={EN=ArticleExt(id=1236679389044339683, articleId=1236679388700406753, tenantId=1146029695717560320, journalId=1210938733613449225, language=EN, title=Techno-economic analysis of coal-fired power plant integrated with proton exchange membrane electrolyzer, columnId=1236679385139434073, journalTitle=Thermal Power Generation, columnName=Special topic of low-carbon power technology, runingTitle=null, highlight=null, articleAbstract=

The proton exchange membrane (PEM) electrolyzer can convert green electricity into hydrogen energy, but the conversion efficiency of PEM electrolyzer is low, the thermal energy in the electrolyzer outlet water is not fully utilized. To fully use the waste heat in the PEM electrolyzer hydrogen production system, integrated systems incorporating a 660 MW coal-fired unit and PEM electrolyzer are proposed in both power generation (PG) and combined heat and power (CHP) scenarios. EBSILON and MATLAB Simulink softwares are applied for modelling, and thermodynamic and economic analysis is conducted. In PG scenario, the electrolyzer outlet water is used to heat the feedwater of coal-fired unit. While for CHP scenario, the electrolyzer outlet water is used to heat the return water from heating supply network along with the extraction steam. The produced oxygen is sent into the boiler for combustion. The results show that, compared with the reference coal-fired unit, in PG scenario, the power output is enhanced by 2.55 MW with an power supply efficiency rise of 0.17%, and the boiler efficiency increases by 0.04%. While in CHP scenario, the power output can be enhanced by 5.83 MW with an efficiency rise of 0.40%. After attributing the net power output increment to the PEM hydrogen production system, the exergy efficiency of the PEM hydrogen production system is 69.74% in PG mode with an increase of 3.44%, and 75.41% in CHP mode with an increase of 9.11%. For these two scenarios, the system exergy efficiencies reach up to 40.20% and 40.18%. Economic analysis shows that, the annual income growth by selling electricity for PG and CHP scenarios are 5 460 000 yuan and 12 460 000 yuan, with the increments of net present value of 61 320 000 yuan and 140 140 000 yuan, respectively. The levelized cost of hydrogen production in the reference system is 42.72 yuan/kg. The levelized cost of hydrogen production in PG and CHP modes in the integrated system is 42.55 yuan/kg and 40.79 yuan/kg, respectively.

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质子交换膜（proton exchange membrane，PEM）电解槽可以将绿电转化为氢能，但PEM电解槽的能量转化效率较低，电解槽出口水的能量未被充分利用。为了充分利用PEM电解制氢系统中的余热，在发电和热电联产2种运行模式下，提出了集成660 MW燃煤电站和PEM电解槽的耦合系统；使用EBSILON和MATLAB Simulink软件进行建模，并对系统进行了热力学和经济性分析。提出发电模式中，将电解槽的出口水用于加热燃煤机组的给水；在热电联产模式中，将电解槽的出口水与抽汽共同用于加热供热网络的回水；产生的氧气输送到锅炉中燃烧，进而促进炉内燃烧。结果显示：与参考燃煤电站相比，发电模式中的供电量增加了2.55 MW，供电效率提高了0.17百分点，锅炉效率提高了0.04百分点；热电联产模式中，供电量增加了5.83 MW，系统总效率提高了0.40百分点。将机组出功增加量折算到PEM制氢系统后，在发电模式下PEM制氢系统的㶲效率达到69.74%，提高了3.44百分点；在热电联产模式下PEM制氢系统的㶲效率达到75.41%，提高了9.11百分点。2种模式下的系统㶲效率分别为40.20%和40.18%。电解制氢经济性分析显示：发电和热电联产模式的年售电收入增长分别为546万元和1 246万元，净现值增长分别为6 132万元和14 014万元；独立系统中的平准化制氢成本为42.72元/kg；集成后发电和热电联产模式下的平准化制氢成本分别为42.55、40.79元/kg。

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孔艳强（1989），男，副教授，主要研究方向为能源动力系统节能与优化，。
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陈志董（1996），男，博士研究生，主要研究方向为能源动力系统节能与优化，。

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陈志董（1996），男，博士研究生，主要研究方向为能源动力系统节能与优化，。

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陈志董（1996），男，博士研究生，主要研究方向为能源动力系统节能与优化，。

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figureFileSmall=dKrZbT+i4MDwmiyFsA1NWg==, figureFileBig=1YuucUMu4lvu9C1PGrOK3g==, tableContent=null), ArticleFig(id=1236679398657683810, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Fig.6, caption=Variation of extraction steam flow rate, figureFileSmall=UBC8PKyYDtmriQx6tqRUeQ==, figureFileBig=CdmyztkYAAE2MLnYnNE+Sw==, tableContent=null), ArticleFig(id=1236679398758347109, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=图6, caption=抽汽量变化, figureFileSmall=UBC8PKyYDtmriQx6tqRUeQ==, figureFileBig=CdmyztkYAAE2MLnYnNE+Sw==, tableContent=null), ArticleFig(id=1236679398842233197, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Fig.7, caption=EUD analysis results, figureFileSmall=6djMk9pJ+gIcl9PtPXDN9w==, figureFileBig=nXvgAcBzkhATc0L0eT/Amg==, tableContent=null), ArticleFig(id=1236679398921924975, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=图7, caption=EUD分析结果, figureFileSmall=6djMk9pJ+gIcl9PtPXDN9w==, figureFileBig=nXvgAcBzkhATc0L0eT/Amg==, tableContent=null), ArticleFig(id=1236679399026782582, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Fig.8, caption=Energy flow charts of the reference coal-fired power unit and PEM electrolyzer in isolated system, figureFileSmall=3g6Agn7XTTqQim9uaFEyYw==, figureFileBig=IURq0B9MGlyI1JAAUzcYPw==, tableContent=null), ArticleFig(id=1236679399144223098, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=图8, caption=独立系统中参考燃煤机组和PEM电解槽的能流图, figureFileSmall=3g6Agn7XTTqQim9uaFEyYw==, figureFileBig=IURq0B9MGlyI1JAAUzcYPw==, tableContent=null), ArticleFig(id=1236679399270052224, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Fig.9, caption=Energy flow charts of the integrated system in PG and CHP scenarios, figureFileSmall=ulDN61GDLEvoEU7Twns3sw==, figureFileBig=rSIZoQCmNP9nJZT8vBAeuA==, tableContent=null), ArticleFig(id=1236679399421047173, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=图9, caption=集成系统在发电模式和热电联产模式下的能流图, figureFileSmall=ulDN61GDLEvoEU7Twns3sw==, figureFileBig=rSIZoQCmNP9nJZT8vBAeuA==, tableContent=null), ArticleFig(id=1236679399538487692, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Fig.10, caption=Variation curves of NPV increment of the integrated system during the lifespan, figureFileSmall=fKMOK6lojKMO2gWrhtOWtg==, figureFileBig=+WS1OcJNhrL5KIhsCZr/Vg==, tableContent=null), ArticleFig(id=1236679399630762385, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=图10, caption=净现值增量在电站寿命期内的变化曲线, figureFileSmall=fKMOK6lojKMO2gWrhtOWtg==, figureFileBig=+WS1OcJNhrL5KIhsCZr/Vg==, tableContent=null), ArticleFig(id=1236679399735619987, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.1, caption=

Operational parameters of the PEM electrolyzer

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
运行压力/MPa0.10
电解槽进口水温/℃70.00
电解槽出口水温/℃94.80
运行电压/V1.90
电流密度/(mA·cm–2)2 602.62
电解槽总水流量/(kg·s–1)162.00
), ArticleFig(id=1236679399836283290, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表1, caption=

PEM电解槽运行参数

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
运行压力/MPa0.10
电解槽进口水温/℃70.00
电解槽出口水温/℃94.80
运行电压/V1.90
电流密度/(mA·cm–2)2 602.62
电解槽总水流量/(kg·s–1)162.00
), ArticleFig(id=1236679399932752283, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.2, caption=

Thermodynamic parameters of the reference coal-fired unit under design condition

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
煤耗量/(kg·s–1)61.94
主蒸汽温度/℃566.0
压力/MPa24.61
流量/(kg·s–1)505.91
再热蒸汽温度/℃566.0
压力/MPa3.77
流量/(kg·s–1)434.48
发电量Pgross/MW660.60
厂用电量（发电量的6%）/MW39.64
供电量Pnet/MW620.96
供电效率ηnet/%42.14
), ArticleFig(id=1236679400041804192, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表2, caption=

参考燃煤机组在设计工况的热力参数

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
煤耗量/(kg·s–1)61.94
主蒸汽温度/℃566.0
压力/MPa24.61
流量/(kg·s–1)505.91
再热蒸汽温度/℃566.0
压力/MPa3.77
流量/(kg·s–1)434.48
发电量Pgross/MW660.60
厂用电量（发电量的6%）/MW39.64
供电量Pnet/MW620.96
供电效率ηnet/%42.14
), ArticleFig(id=1236679401526587814, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.3, caption=

Basic parameters of the heating supply system

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
热网供水温度/℃90.00
热网回水温度/℃50.00
换热器热流体（抽汽）进口温度/℃369.23
换热器热流体出口温度/℃85.00
供热量/MW36.88
), ArticleFig(id=1236679401627251115, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表3, caption=

供热系统的基本参数

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
热网供水温度/℃90.00
热网回水温度/℃50.00
换热器热流体（抽汽）进口温度/℃369.23
换热器热流体出口温度/℃85.00
供热量/MW36.88
), ArticleFig(id=1236679401732108717, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.4, caption=

System performance in PG scenario

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
煤耗量/(kg·s–1)61.9461.94
煤的输入能量/MW1 473.551 473.55
主蒸汽流量/(kg·s–1)505.91506.93
再热蒸汽流量/(kg·s–1)434.48434.95
发电量/MW660.60663.15
厂用电量/MW39.6439.64
锅炉效率/%92.6792.71
供电量/MW620.96623.51
供电效率/%42.1442.31
), ArticleFig(id=1236679401845354927, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表4, caption=

发电模式下系统性能

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
煤耗量/(kg·s–1)61.9461.94
煤的输入能量/MW1 473.551 473.55
主蒸汽流量/(kg·s–1)505.91506.93
再热蒸汽流量/(kg·s–1)434.48434.95
发电量/MW660.60663.15
厂用电量/MW39.6439.64
锅炉效率/%92.6792.71
供电量/MW620.96623.51
供电效率/%42.1442.31
), ArticleFig(id=1236679401937629622, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.5, caption=

Exergy analysis results in PG scenario

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
㶲输入/MW煤1 587.381 587.38
可再生能源57.9457.94
总和1 645.321 645.32
㶲损失/MW锅炉779.29778.97
汽轮机46.8547.21
回热器17.1216.47
凝汽器75.5077.17
发电机8.028.05
厂用电39.6439.64
电解槽15.6215.62
HX3.910.82
总和985.95983.95
㶲输出/MW电620.96623.51
氢气37.8637.86
氧气0.55
总和659.37661.37
PEM制氢系统㶲效率/%66.3069.74
总㶲效率/%40.0740.20
), ArticleFig(id=1236679402088624570, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表5, caption=

发电模式下的㶲分析结果

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
㶲输入/MW煤1 587.381 587.38
可再生能源57.9457.94
总和1 645.321 645.32
㶲损失/MW锅炉779.29778.97
汽轮机46.8547.21
回热器17.1216.47
凝汽器75.5077.17
发电机8.028.05
厂用电39.6439.64
电解槽15.6215.62
HX3.910.82
总和985.95983.95
㶲输出/MW电620.96623.51
氢气37.8637.86
氧气0.55
总和659.37661.37
PEM制氢系统㶲效率/%66.3069.74
总㶲效率/%40.0740.20
), ArticleFig(id=1236679402231230910, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.6, caption=

System performance in CHP scenario

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
煤耗量/(kg·s–1)61.9461.94
煤的输入能量/MW1 473.551 473.55
主蒸汽流量/(kg·s–1)505.91506.93
再热蒸汽流量/(kg·s–1)434.48434.95
抽汽流量/(kg·s–1)13.006.90
发电量/MW649.54655.37
厂用电量/MW39.6439.64
供电量/MW609.90615.73
供热量/MW36.8836.88
系统总效率/%43.8944.29
), ArticleFig(id=1236679402331894212, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表6, caption=

热电联产模式下的系统性能

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
煤耗量/(kg·s–1)61.9461.94
煤的输入能量/MW1 473.551 473.55
主蒸汽流量/(kg·s–1)505.91506.93
再热蒸汽流量/(kg·s–1)434.48434.95
抽汽流量/(kg·s–1)13.006.90
发电量/MW649.54655.37
厂用电量/MW39.6439.64
供电量/MW609.90615.73
供热量/MW36.8836.88
系统总效率/%43.8944.29
), ArticleFig(id=1236679402428363210, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.7, caption=

Exergy analysis results in CHP scenario

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
㶲输入/MW煤1 587.381 587.38
可再生能源57.9457.94
总和1 645.321 645.32
㶲损失/MW锅炉779.09778.77
汽轮机46.2746.41
回热器16.5416.35
凝汽器73.1674.68
发电机7.897.96
厂用电39.6439.64
电解槽15.6215.62
HX3.911.00
HX17.403.81
总和989.52984.24
㶲输出/MW电609.90615.73
热7.497.49
氢气37.8637.86
氧气0.55
总和655.8661.08
PEM制氢系统㶲效率/%66.3075.41
总㶲效率/%39.8640.18
), ArticleFig(id=1236679402520637898, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表7, caption=

热电联产模式下的㶲分析结果

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
㶲输入/MW煤1 587.381 587.38
可再生能源57.9457.94
总和1 645.321 645.32
㶲损失/MW锅炉779.09778.77
汽轮机46.2746.41
回热器16.5416.35
凝汽器73.1674.68
发电机7.897.96
厂用电39.6439.64
电解槽15.6215.62
HX3.911.00
HX17.403.81
总和989.52984.24
㶲输出/MW电609.90615.73
热7.497.49
氢气37.8637.86
氧气0.55
总和655.8661.08
PEM制氢系统㶲效率/%66.3075.41
总㶲效率/%39.8640.18
), ArticleFig(id=1236679402596135375, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.8, caption=

Basic data for economic analysis

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
上网电价ce/(元·(kW·h)–1)0.427[13]
年运行时间H/h5 000
燃煤电站寿命n/a30[14]
折现率k/%8.0[13]
), ArticleFig(id=1236679402659049940, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表8, caption=

经济性计算基本数据

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
上网电价ce/(元·(kW·h)–1)0.427[13]
年运行时间H/h5 000
燃煤电站寿命n/a30[14]
折现率k/%8.0[13]
), ArticleFig(id=1236679402751324633, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.9, caption=

Basic data for investment cost calculation for heat exchanges

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
HX1HX1HX
类型管壳式管壳式板式
换热面积/m2250.0150.0250.0
投资成本/(×103元)192.50116.9759.99
总投资成本/(×103元)192.5176.96
), ArticleFig(id=1236679402831016414, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表9, caption=

换热器投资成本计算基本数据

, figureFileSmall=null, figureFileBig=null, tableContent=
项目独立系统集成系统
HX1HX1HX
类型管壳式管壳式板式
换热面积/m2250.0150.0250.0
投资成本/(×103元)192.50116.9759.99
总投资成本/(×103元)192.5176.96
), ArticleFig(id=1236679402940068323, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.10, caption=

Economic analysis results

, figureFileSmall=null, figureFileBig=null, tableContent=
项目模式
发电热电联产
供电量增量ΔP/MW2.555.83
年供电量增量/(GW·h)12.7529.15
年售电收入增量ΔCin/万元5461 246
净现值增量NPV/万元6 13214 014
), ArticleFig(id=1236679403011371495, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表10, caption=

经济性分析结果

, figureFileSmall=null, figureFileBig=null, tableContent=
项目模式
发电热电联产
供电量增量ΔP/MW2.555.83
年供电量增量/(GW·h)12.7529.15
年售电收入增量ΔCin/万元5461 246
净现值增量NPV/万元6 13214 014
), ArticleFig(id=1236679403082674668, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=EN, label=Tab.11, caption=

Calculation results of levelized cost of hydrogen production LCOH

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
电解槽单位成本/(元·kW–1)6 000[17]
换热器单位成本/(元·m–2)1 150[17]
每套制氢电源成本/万元1 700[17]
每套纯水制备设备/万元200[17]
水价/(元·t–1)7[17]
独立系统中的平准化制氢成本LCOH/(元·kg–1)42.72
发电模式下折算的平准化制氢成本LCOH, PG/(元·kg–1)42.55
热电联产模式下折算的平准化
制氢成本LCOH, CHP/(元·kg–1)		40.79
), ArticleFig(id=1236679403162366449, tenantId=1146029695717560320, journalId=1210938733613449225, articleId=1236679388700406753, language=CN, label=表11, caption=

平准化制氢成本计算结果

, figureFileSmall=null, figureFileBig=null, tableContent=
项目数值
电解槽单位成本/(元·kW–1)6 000[17]
换热器单位成本/(元·m–2)1 150[17]
每套制氢电源成本/万元1 700[17]
每套纯水制备设备/万元200[17]
水价/(元·t–1)7[17]
独立系统中的平准化制氢成本LCOH/(元·kg–1)42.72
发电模式下折算的平准化制氢成本LCOH, PG/(元·kg–1)42.55
热电联产模式下折算的平准化
制氢成本LCOH, CHP/(元·kg–1)		40.79
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质子交换膜电解槽与燃煤电站耦合的技术经济性分析
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陈志董 , 张菁 , 詹宏伟 , 孔艳强 , 杨立军 , 杜小泽
热力发电 | 低碳电力技术研究专题 2024,53(12): 10-20
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热力发电 | 低碳电力技术研究专题 2024, 53(12): 10-20
质子交换膜电解槽与燃煤电站耦合的技术经济性分析
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陈志董 , 张菁, 詹宏伟, 孔艳强 , 杨立军, 杜小泽
作者信息
  • 华北电力大学电站能量传递转化与系统教育部重点实验室，北京　102206

    • 陈志董（1996），男，博士研究生，主要研究方向为能源动力系统节能与优化，。

通讯作者:

孔艳强（1989），男，副教授，主要研究方向为能源动力系统节能与优化，。
Techno-economic analysis of coal-fired power plant integrated with proton exchange membrane electrolyzer
Zhidong CHEN , Jing ZHANG, Hongwei ZHAN, Yanqiang KONG , Lijun YANG, Xiaoze DU
Affiliations
  • Key Laboratory of Power Station Energy Transfer Conversion and System of Ministry of Education, North China Electric Power University, Beijing 102206, China
出版时间: 2024-12-25 doi: 10.19666/j.rlfd.202405131
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质子交换膜（proton exchange membrane，PEM）电解槽可以将绿电转化为氢能，但PEM电解槽的能量转化效率较低，电解槽出口水的能量未被充分利用。为了充分利用PEM电解制氢系统中的余热，在发电和热电联产2种运行模式下，提出了集成660 MW燃煤电站和PEM电解槽的耦合系统；使用EBSILON和MATLAB Simulink软件进行建模，并对系统进行了热力学和经济性分析。提出发电模式中，将电解槽的出口水用于加热燃煤机组的给水；在热电联产模式中，将电解槽的出口水与抽汽共同用于加热供热网络的回水；产生的氧气输送到锅炉中燃烧，进而促进炉内燃烧。结果显示：与参考燃煤电站相比，发电模式中的供电量增加了2.55 MW，供电效率提高了0.17百分点，锅炉效率提高了0.04百分点；热电联产模式中，供电量增加了5.83 MW，系统总效率提高了0.40百分点。将机组出功增加量折算到PEM制氢系统后，在发电模式下PEM制氢系统的㶲效率达到69.74%，提高了3.44百分点；在热电联产模式下PEM制氢系统的㶲效率达到75.41%，提高了9.11百分点。2种模式下的系统㶲效率分别为40.20%和40.18%。电解制氢经济性分析显示：发电和热电联产模式的年售电收入增长分别为546万元和1 246万元，净现值增长分别为6 132万元和14 014万元；独立系统中的平准化制氢成本为42.72元/kg；集成后发电和热电联产模式下的平准化制氢成本分别为42.55、40.79元/kg。

质子交换膜电解槽  /  燃煤电站  /  制氢  /  技术经济性分析

The proton exchange membrane (PEM) electrolyzer can convert green electricity into hydrogen energy, but the conversion efficiency of PEM electrolyzer is low, the thermal energy in the electrolyzer outlet water is not fully utilized. To fully use the waste heat in the PEM electrolyzer hydrogen production system, integrated systems incorporating a 660 MW coal-fired unit and PEM electrolyzer are proposed in both power generation (PG) and combined heat and power (CHP) scenarios. EBSILON and MATLAB Simulink softwares are applied for modelling, and thermodynamic and economic analysis is conducted. In PG scenario, the electrolyzer outlet water is used to heat the feedwater of coal-fired unit. While for CHP scenario, the electrolyzer outlet water is used to heat the return water from heating supply network along with the extraction steam. The produced oxygen is sent into the boiler for combustion. The results show that, compared with the reference coal-fired unit, in PG scenario, the power output is enhanced by 2.55 MW with an power supply efficiency rise of 0.17%, and the boiler efficiency increases by 0.04%. While in CHP scenario, the power output can be enhanced by 5.83 MW with an efficiency rise of 0.40%. After attributing the net power output increment to the PEM hydrogen production system, the exergy efficiency of the PEM hydrogen production system is 69.74% in PG mode with an increase of 3.44%, and 75.41% in CHP mode with an increase of 9.11%. For these two scenarios, the system exergy efficiencies reach up to 40.20% and 40.18%. Economic analysis shows that, the annual income growth by selling electricity for PG and CHP scenarios are 5 460 000 yuan and 12 460 000 yuan, with the increments of net present value of 61 320 000 yuan and 140 140 000 yuan, respectively. The levelized cost of hydrogen production in the reference system is 42.72 yuan/kg. The levelized cost of hydrogen production in PG and CHP modes in the integrated system is 42.55 yuan/kg and 40.79 yuan/kg, respectively.

proton exchange membrane electrolyzer  /  coal-fired power station  /  hydrogen production  /  techno-economic analysis
陈志董, 张菁, 詹宏伟, 孔艳强, 杨立军, 杜小泽. 质子交换膜电解槽与燃煤电站耦合的技术经济性分析. 热力发电, 2024 , 53 (12) : 10 -20 . DOI: 10.19666/j.rlfd.202405131
Zhidong CHEN, Jing ZHANG, Hongwei ZHAN, Yanqiang KONG, Lijun YANG, Xiaoze DU. Techno-economic analysis of coal-fired power plant integrated with proton exchange membrane electrolyzer[J]. Thermal Power Generation, 2024 , 53 (12) : 10 -20 . DOI: 10.19666/j.rlfd.202405131
正文
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近年来可再生能源发展迅速，但可再生能源的大规模并网会对电网造成危害。在这种情况下，可以利用可再生能源制氢将间歇性的可再生能源转化为长期可储存的氢能[1]，同时大大减少工业生产中的碳排放。近年来，利用电解水技术制氢越来越受到人们的关注。电解水制氢技术主要包括碱性电解水、阴离子交换膜电解水、质子交换膜（proton exchange membrane，PEM）电解水和固体氧化物电解水。碱性电解水技术已经成熟，但反应缓慢，不适合利用波动的可再生能源生产氢气。阴离子交换膜电解水和固体氧化物电解水仍处于研究阶段，尚未广泛商业化[2]。而PEM电解槽的结构特征使其具有高电流密度以及快速响应负荷的优势，这使其适用于利用波动的可再生能源制氢[3-4]。
随着PEM电解技术的发展，许多学者开始关注将PEM电解与可再生能源及其他热力系统进行集成。Abdollahipour等人[5]提出了一种用于发电的PEM电解槽和PEM燃料电池的集成系统，并进行了多目标优化分析。Gu等人[6]构建了光伏电池PEM电解水系统模型，并提出了实现全天稳定制氢的能源管理策略。María等人[7]提出了一种耦合PEM电解槽、有机朗肯循环和余热回收的集成系统，并进行了技术经济分析。Zhao等人[8]提出并对包含不对称PEM电解槽和固体氧化物燃料电池的储氢系统进行了热力学分析。Chen等人[9]将PEM电解槽与光伏直接进行耦合，并提出运行策略以实现集成系统的安全高效运行。
综上所述，许多学者已经对PEM电解槽的系统集成进行了广泛研究，但关于PEM电解与燃煤电站的集成研究较少。而PEM电解槽目前存在能量转化效率不高的问题。因此，如何通过系统集成对PEM电解制氢系统中的余热进行充分利用有待进一步探索。基于此，本文针对目前燃煤电站在发电和热电联产模式下的系统流程，提出将PEM电解槽与燃煤电站分别在发电模式和热电联产模式下进行耦合的集成系统，并对其进行热力学分析和经济性分析，给出了PEM电解槽出口水能量梯级利用方案，并分析了集成方案的热力学和经济性可行性，有助于其在工程实际中的应用。
1　系统描述
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1.1　PEM电解槽
图1给出了基于可再生能源的PEM电解制氢系统示意。可再生能源的电力用于驱动PEM电解槽电解水，水从阳极进入电解槽，并在电能的驱动下发生电化学反应，分别在阳极和阴极分解为氧气和氢气（式(1)、式(2)）。
2H2O→4H++O2+4e−  
4H++4e−→2H2
氧和水的混合物从阳极出口离开电解槽，进入分离器中分离水和氧气。氢气和水的混合物从阴极离开电解槽，进入分离器分离水和氢气。分离器排出的水与补充水混合，然后泵入电解槽进行电解。由于电解过程电压高于热中性电压，反应会释放热量，电解槽中的水会吸收热量温度升高。因此，气水分离后的水在进入电解槽之前需要经过冷却降温。有效利用这部分热量可以大幅提升系统经济性。电解槽主要运行参数见表1。
1.2　燃煤电站
参考燃煤电站为超临界660 MW机组，由煤粉锅炉、一次再热汽轮机（包括高压缸、中压缸和低压缸）、回热系统、凝汽器和发电机组成。煤粉在锅炉中燃烧放出热量，锅炉给水在锅炉中吸热后变成高温高压蒸汽，进入汽轮机中驱动汽轮机发电。该燃煤电站主要在发电和热电联产2种模式下运行，系统结构示意如图2和图3所示。
1）发电模式下参考燃煤机组基本热力数据见表2。由于主蒸汽和再热蒸汽的参数相对较高，蒸汽循环相对完善，该燃煤机组的供电效率为42.14%。
2）当燃煤机组在热电联产模式下运行时，中压缸出口的抽汽用于加热供热网的回水。因此，热电联产机组的能量输出是电和热。对外进行供热可以提高燃煤机组的热效率，供热系统参数见表3。中压缸出口抽汽的质量流量可以根据供热负荷改变。
1.3　集成系统
发电和热电联产模式下的集成系统如图4和图5所示。
1）在发电模式中，可再生能源的电力用来驱动PEM电解槽制氢。水在PEM电解槽中吸收电化学反应产生的热量，温度升高。部分水经过电化学反应变成氢气和氧气。PEM电解槽出口水进入换热器HX中与凝结水泵出口的部分给水换热。换热之后，电解槽的出口水温度降低，随后回到电解槽中继续制氢。在HX中换热之后，这部分给水的温度升高，随后输送到回热器RH6中。电解槽中产生的氧气与空气混合，然后送入锅炉的炉膛与煤粉混合燃烧。同时，产生的氢气经过干燥纯化后储存备用。
2）在热电联产模式中，可再生能源的电力用来驱动PEM电解槽制氢，PEM电解槽的出口水温度升高。PEM电解槽的出口水首先进入HX加热来自供热管网的回水。在HX中换热之后，电解槽的出口水温度降低，随后回到电解槽中继续制氢。在HX中换热之后，升温后的热网回水进入换热器HX1中，与中压缸出口的抽汽换热。抽汽在换热之后变成凝结水，与RH5的进口给水混合，进入RH5吸热。管网回水在换热器HX1中吸收热量后，温度升高，作为热网供水回到供热管网。HX为水/水换热器，内部发生的换热过程温度较低（不超过100 ℃），且压力在1 MPa左右，在工业应用可以使用板式换热器。而HX1为蒸汽/水换热器，在实际运行中内部发生高温、高压换热过程，一般在电厂中使用管壳式换热器。与发电模式一样，电解槽中产生的氧气与空气混合，然后送入炉膛与煤粉燃烧，电解槽中产生的氢气进行干燥纯化后储存备用。
2　建模及数值计算
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2.1　系统建模
本文使用EBSILON软件对燃煤电站进行建模；使用MATLAB Simulink软件对PEM电解过程进行建模，PEM电解过程的建模基于文献[10]。
对系统进行热力学和经济性分析时，做如下假设：1）在发电和热电联产模式中，煤耗量保持不变；2）在发电和热电联产模式中，燃煤电站厂用电量保持不变；3）PEM电解槽入口和出口水温、入口水流量保持不变；4）环境空气由21%（体积分数，下同）的O2和79%的N2组成；5）系统在稳态下运行。
2.2　分析方法
2.2.1　能量分析
本文用供电效率（ηnet）评价燃煤电站在发电模式下的性能，用系统总效率（ηtotal）评价燃煤电站在热电联产模式下的性能。独立系统中的参考燃煤电站和集成系统在发电模式时，机组的供电效率ηnet计算公式为[11]：
ηnet=PnetQLHV,coal⋅mcoal
式中：Pnet为供电量，MW；QLHV,coal为煤的低位发热量，MJ/kg；mcoal为煤耗量，kg/s。
对于独立系统中的参考燃煤电站和集成系统在热电联产模式时，系统总效率ηtotal计算公式为：
ηtotal=Pnet+QheatingQLHV,coal⋅mcoal
式中：Qheating为供热量，MW。
2.2.2　㶲分析
㶲分析可以识别热力系统中导致热力学低效的源头[12]。本文从热力学第二定律的角度，采用㶲效率ηex评估系统的性能。在发电模式时，独立系统（包括参考燃煤机组和PEM电解系统）和集成系统的㶲效率ηex, PG计算公式为[9]：
ηex, PG=Pnet+EXhydrogen+EXoxygenEXcoal+EXrenewele
式中：EXhydrogen和EXoxygen分别为氢气和氧气的㶲，MW；EXcoal为煤的㶲，MW；EXrenewele为输入可再生能源电力的㶲，MW。
在热电联产模式下，独立系统（包括参考燃煤机组和PEM电解系统）和集成系统的㶲效率ηex, CHP计算公式为：
ηex, CHP=Pnet+EXheating+EXhydrogen+EXoxygenEXcoal+EXrenewele
式中：EXheating为供热输出的总㶲，MW。
此外，将PEM制氢系统与燃煤机组进行集成后，在发电模式和热电联产模式下，集成系统的供电量都会提升。因此，可以将这部分增加的出功折算到PEM制氢系统的产出，来分析集成对PEM制氢系统㶲效率的提升。集成之前PEM制氢系统的㶲效率为：
ηPEM=EXhydrogen+EXoxygenEXrenewele
集成之后PEM制氢系统在发电模式和热电联产模式下的㶲效率可以分别计算为：
ηPEM, PG=ΔPnet, PG+EXhydrogenEXrenewele
ηPEM, CHP=ΔPnet， CHP+EXhydrogenEXrenewele
式中：ΔPnet,PG和ΔPnet,CHP分别为集成系统在发电模式和热电联产模式下的供电量的增加量，MW。
3　结果与讨论
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3.1　发电模式
发电模式下燃煤机组的系统性能见表4。由表4可见，在独立系统和集成系统中，煤耗量和能量输入保持不变。在集成系统中，主蒸汽流量和再热蒸汽流量都略有增加，因为氧气被送入锅炉进行燃烧，锅炉吸热量增加。由于氧气改善了锅炉的燃烧，集成系统的锅炉效率提高了0.04百分点。集成系统的供电量增加了2.55 MW，供电效率提高了0.17百分点。
由于电解槽出口水用于加热部分RH6进口给水，因此燃煤机组的抽汽量将发生变化，具体如图6所示。由图6可见：与参考燃煤机组相比，由于给水流量略有增加，1—5号抽汽的流量略有增加；因为部分给水被电解槽的出口水加热，因此替代了部分抽汽，所以7号和8号抽汽的流量明显降低；并且由于HX的出口给水温度高于RH7出口给水，所以6号抽汽的流量也有一定的降低。
发电模式下集成系统的㶲分析结果见表5。由表5可见，煤和可再生能源的㶲输入分别为1 587.38 MW和57.94 MW。与独立系统相比，由于输送进入锅炉的氧气改善了炉内燃烧，因此集成系统中锅炉的㶲损失略有降低。集成系统中的蒸汽流量和功率输出较高，因此汽轮机、冷凝器和发电机的㶲损失较大。由于集成系统中所需的抽汽量降低，回热系统的㶲损失得以减少。由于电解槽出口水中的㶲用于加热给水，因此换热器（HX）中的㶲损失大大减少，这也有助于减少回热系统的㶲损。集成之前PEM制氢系统的㶲效率为66.30%；集成之后PEM制氢系统的㶲效率为69.74%，提升了3.44百分点。总体而言，集成系统的㶲效率为40.20%，比独立系统高0.13百分点。
3.2　热电联产模式
热电联产模式中集成系统的性能见表6。供热能量由抽汽和电解槽的出口水提供。在供热量不变的情况下，由于抽汽流量从13.00 kg/s大幅降低到6.90 kg/s，因此更多的蒸汽可以用来在汽轮机内做功，所以集成系统的供电量增加了5.83 MW。与独立系统相比，系统总效率提高了0.40百分点。
为了揭示集成系统中的节能机理，本文对2个系统中换热器的换热过程进行了图像㶲（EUD）分析，进而阐明换热器内部的传热状况。EUD分析结果如图7所示。利用能级（A）来表示能量品位[13]：
A=ΔEXΔQ=1−T0ΔSΔQ=1−T0T
式中：ΔEX为㶲的变化，kW；ΔQ为能量的变化，kW；ΔS为熵变，kW/K；T0为环境温度，298.15 K；T为热流体温度，K。
由图7可见：在独立系统的HX1中，由于抽汽和供水之间的温差较大，㶲损失高达7.40 MW；在集成系统中，HX和HX1中的㶲损失分别为1.00 MW和3.81 MW，总的㶲损失为4.81 MW。与独立系统中的㶲损失相比，由于电解槽的出口水与供水之间的温差大大减小，因此换热㶲损得到有效降低。因此，换热器中㶲损失的降低有助于系统提高性能。
热电联产模式中集成系统的㶲分析结果见表7。集成系统中的蒸汽流量和功率输出较高，所以汽轮机、凝汽器和发电机的㶲损失增加。因为回水依次被抽汽和电解槽出口水加热，从而大大降低了传热温差，HX和HX1的㶲损失大大降低。集成系统的电和供热的㶲输出分别为615.73 MW和7.49 MW，氢气的㶲输出为37.86 MW。集成之前PEM制氢系统的㶲效率为66.30%；集成之后PEM制氢系统的㶲效率为75.41%，提升了9.11百分点。集成系统的总㶲效率为40.18%，比独立系统高0.32百分点。
3.3　能流图
本文对参考燃煤电站、电解槽以及发电和热电联产模式中系统的能量流动情况进行了分析，具体如图8和图9所示。煤和可再生能源电力的能量输入保持不变，分别为1 473.55 MW和57.94 MW。
由图8可见：在发电模式下，燃煤机组的功率输出为620.96 MW；而在热电联产模式下，燃煤机组的功率输出为609.90 MW，供热量输出为36.88 MW。电解槽的氢气输出能量为38.78 MW，而在HX中的能量损失为18.14 MW。由图9可见：由于氧气的能量被输入到锅炉中，因此主蒸汽和再热蒸汽吸收了更多的能量，为1 991.71 MW。此外，电解槽出口水的能量被输送到燃煤机组的蒸汽循环中。因此，在发电和热电联产2种模式下，集成系统中燃煤机组的功率输出都高于参考燃煤机组。集成系统在发电和热电联产模式下的功率输出分别为623.51 MW和615.73 MW。热电联产模式的供热输出由电解槽的出口水和抽汽提供，分别为18.14 MW和18.74 MW。
4　经济性分析
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与独立系统燃煤机组相比，集成系统成本变化只涉及到换热器的设备成本，具体如下。
1）基于发电模式，集成系统无需改造，因为原本PEM电解槽中的水/水热交换器（HX）可直接用于加热燃煤机组给水，所以无需增加购买设备的成本。而在集成系统中，将电解槽的出口水用来加热燃煤机组的低加给水，可以替代燃煤机组7号和8号抽汽，机组发电量也得到了提升，输出电功率增加。因此，集成系统可以通过输出更多电功，从而获得更多售电收益。
2）基于热电联产模式，集成系统需要增加1个水/水换热器HX。因为集成系统中的HX1的换热量小于参考燃煤机组中的HX1，因此集成系统的HX1的换热面积应小于参考燃煤机组中的HX1。所以，集成系统所需的设备投资成本将取决于新增换热器的成本。集成系统利用电解槽的出口水来加热供热网回水，大幅降低了燃煤机组的供热抽汽流量，机组的发电量也得到了提升。因此，集成系统的输出电功率更多，售电收益也会增加。
表8给出了经济性分析的基本数据。本文选择净现值（NPV）作为评价标准来计算集成系统在寿命内的净现值增量。净现值增量计算如下：
NPV=∑y=1nΔCin(1+k)y−Cout
式中：k为折现率；y为电厂寿命内的年数；ΔCin为第y年的资金收入，元；Cout为设备成本，元。
集成系统在发电和热电联产模式时，ΔCin计算公式为：
ΔCin=ΔP⋅H⋅ce
式中：ce为上网电价，元/(kW·h)；ΔP为集成系统发电量的增量，MW；H为电厂的年运行时间，h。
集成系统在发电模式下时，Cout为零。集成系统在热电联产模式下时，Cout计算公式为：
Cout=ΔCequipment
式中：ΔCequipment为购买设备成本的增量，元。
表9给出了2个系统中HX投资的计算数据（从设备制造商处获得[15]）。独立系统中的换热器为管壳式换热器（HX1）。而在集成系统中管壳式换热器的面积较小（HX1），并补充了板式换热器（HX），尽管板式换热器（HX）的面积与独立系统中HX1的面积一样大，但集成系统中的HX1和HX的总成本低于独立系统中HX1的成本，因为与管壳式热交换器相比，板式换热器的单位传热面积成本更低。
经济性分析结果见表10。由表10可见：1）在发电模式下，年发电量增量为12.75 GW·h，通过售电带来的年收入增量为546万元，净现值增量为6 132万元；2）在热电联产模式下，年发电量增量为29.15 GW·h，通过售电带来的年收入增量为1 246万元，净现值增量为14 014万元。随着热电联产模式下发电量的增加，热电联产模式的经济效益增量高于发电模式。总之，集成系统在这2种模式下都有良好的经济性。
图10给出了电站寿命期内集成系统在2种模式下的净现值增量变化曲线。由图10可见，2种模式下的净现值增量都随时间逐渐增加，但增速逐渐放缓。热电联产模式下的净现值增量要比发电模式下的净现值增量更高。
此外，本文还使用平准化制氢成本（LCOH，元/kg）作为评价指标，对独立系统和集成系统的制氢系统进行经济性分析[16]。电解槽制氢系统包括电解槽以及制氢系统的辅助设备（包括制氢电源、换热器和纯水制取设备）。对于独立系统的制氢系统，LCOH为：
LCOH=CCOST, total∑t=1nHannual⋅（1+k）−t=FCI+∑t=1n（W+E）⋅（1+k）−t∑t=1nHannual⋅（1+k）−t
W=Qw⋅cw
E=Qe⋅ce
式中：CCOST, total为制氢系统在全生命周期内的总成本，元；Hannual为制氢系统的年产氢量，kg；FCI为总的设备投资成本，元，包括电解槽、换热器、直流电源和制水设备的成本；W为电解槽总的消耗水的成本，元；E为电解槽总的耗电成本，元；n为设备寿命，取30年；Qw为每年所消耗的水，t；cw为水的单价，元/t；Qe为每年消耗的电量；kW·h；ce为电价，元/(kW·h)。
对于集成系统，如果把集成后系统多发的电量所得经济收益（即净现值增量）折算到制氢系统中，可以降低总制氢成本。则在发电模式和热电联产模式下制氢系统的LCOH可以分别表示为：
LCOH, PG=CCOST, total−NPVPG∑t=1nHannual⋅（1+k）−t
LCOH, CHP=CCOST, total−NPVCHP∑t=1nHannual⋅（1+k）−t
式中：LCOH, PG和LCOH, CHP分别为将发电模式和热电联产模式下的净现值增量（发电收益增量）折算到制氢系统后的平准化制氢成本，元/kg。
计算得到平准化制氢成本见表11。由表11可知，独立系统中的平准化制氢成本为42.72元/kg，发电模式下将净现值增量折算到制氢系统的平准化制氢成本为42.55元/kg，热电联产模式下将净现值增量折算到制氢系统的平准化制氢成本为40.79元/kg，相比独立系统平准化制氢成本有所降低。
5　结论
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本文提出了耦合660 MW燃煤机组和PEM电解槽的集成系统，在发电模式下，电解槽出口水用于加热燃煤机组的给水；而在热电联产模式下，电解槽的出口水用于加热热网回水。通过热力学和经济分析，关键结论如下。
1）集成系统在发电模式中，供电量提高了2.55 MW，效率提高了0.17百分点，锅炉效率提高了0.04百分点。6号、7号和8号抽汽的流量显著降低。在热电联产模式中，供电量增加5.83 MW，效率提高0.40百分点。供热所需的抽汽从13.00 kg/s减少到6.90 kg/s。通过将PEM电解槽与燃煤机组进行集成，系统热力学性能得到改善，发电量和机组效率均得到提升。
2）在发电模式中，PEM制氢系统的㶲效率　达到69.74%，提高了3.44百分点；㶲输出为661.37 MW，系统㶲效率达到40.20%，提高了0.13百分点。在热电联产模式中，PEM制氢系统的㶲效率达到75.41%，提高了9.11百分点；㶲输出为661.08 MW，系统㶲效率为40.18%，提高了0.32%。与原系统相比，集成系统的㶲效率得到了提升，从而系统性能也得到了提升。
3）在发电模式中，年发电量增加12.75 GW·h，净现值增加6 132万元。在热电联产模式中，年发电增量为29.15 GW·h，净现值增加额为14 014万元。独立系统中的平准化制氢成本为42.72元/kg；将净现值增量折算到制氢系统后，发电模式下的平准化制氢成本为42.55元/kg，而热电联产模式下的平准化制氢成本为40.79元/kg。将燃煤机组与PEM制氢系统进行集成后，不需要增加设备投资成本就可以获得较为可观的经济收益，在实际工程应用中具有良好的实用性。
基金
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  • 国家自然科学基金项目(52276062)
  • 国家自然科学基金项目(52076076)
文献
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2024年第53卷第12期
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doi: 10.19666/j.rlfd.202405131
  • 接收时间：2024-05-16
  • 首发时间：2026-03-06
  • 出版时间：2024-12-25
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  • 收稿日期：2024-05-16
基金
National Natural Science Foundation of China(52276062)
国家自然科学基金项目(52276062)
National Natural Science Foundation of China(52076076)
国家自然科学基金项目(52076076)
作者信息
    华北电力大学电站能量传递转化与系统教育部重点实验室，北京　102206

通讯作者:

孔艳强（1989），男，副教授，主要研究方向为能源动力系统节能与优化，。
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2种不同金属材料的力学参数
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Number of
genus		 种数
Number of
species		 占总种数比例
Percentage of
total species (%)		 属
Genus		 种数
Number of
species		 占总种数比例
Percentage of total
species (%)
鹅膏菌科Amanitaceae 2 11 5.26 鹅膏菌属 Amanita 10 4.78
小菇科 Mycenaceae 2 12 5.74 丝盖伞属 Inocybe 5 2.39
多孔菌科 Polyporaceae 8 14 6.70 蜡蘑属 Laccaria 5 2.39
红菇科 Russulaceae 3 23 11.00 小皮伞属 Marasmius 6 2.87
小菇属 Mycena 11 5.26
光柄菇属 Pluteus 5 2.39
红菇属 Russula 17 8.13
栓菌属 Trametes 5 2.39
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