gas for energy Reliability matters (Vorschau)

2013_11_Anzeigeg4e_OH.indd 1 07.11.2013 07:22:16 

03–2013 

www.gas-for-energy.com 

gasforenergy 

ISSN 2192-158X 

Magazine for Smart Gas Technologies, 

Infrastructure and Utilisation 

DIV Deutscher Industrieverlag GmbH 

Gas quality 

in gas systems 

reliability matters 

The natural gas business is demanding. Service 

organizations need a proven solution to measure gas 

flow and correct for volume in custody transfer and 

secondary metering applications. With decades of 

natural gas measurement and control experience, 

RMG by Honeywell has developed the ERZ 2000-NG, 

the approved and best-in-class gas flow measurement 

solution for all areas of gas volume conversion. Competitively priced and offering a low total 

cost-of-ownership, it meets a wide range of application requirements throughout the natural gas 

industry. For further information please go to www.rmg.com/erz2000-ng-en 

To learn more about products and solutions from RMG by Honeywell, 

visit www.rmg.com or www.honeywellprocess.com or contact your account manager. 

© 2013 Honeywell International Inc. All rights reserved

A CLOSE-UP VIEW OF THE 

INTERNATIONAL GAS BUSINESS 

This magazine for smart gas technologies, infrastructure and utilisation 

features technical reports on the European natural gas industry as well as 

results of research programmes and innovative technologies. Find out more about 

markets, enterprises, associations and products of device manufacturers. 

Each edition is completed by interviews with major company leaders and 

interesting portraits of key players in the European business. 

READ MORE ABOUT 

Gas applications Grid infrastructure Measurement 

Gas quality issues Pipeline construction Regulation 

Biogas injection Corrosion protection Smart metering 

on the annual 

Save 25% subscription 

gas for energy is published by DIV Deutscher Industrieverlag GmbH, Arnulfstr. 124, 80636 München 

KNOWLEDGE FOR THE 

FUTURE 

Order now by fax: +49 931 / 4170-494 or send in by mail 

Deutscher Industrieverlag GmbH | Arnulfstr. 124 | 80636 München 

Yes, I want to read gas for energy on a regular basis. During the first year I will benefit from a 25% 

discount on the annual subscription fees. I subscribe to the technical trade journal for at least one 

year (4 issues) 

as a printed magazine at the annual price 

of € 144.00 plus shipping (€ 12.00 within 

Germany / € 14.00 outside of Germany) 

as an e-paper magazine (single user) at 

the annual price of € 144.00. 

as a printed plus an e-paper magazine 

(single user) at the annual price of € 199.20 

(within Germany) / € 201.20 (outside of 

Germany) incl. shipping. 

Special offer for students (proof of entitlement) 

as a printed magazine at the annual price of 

€ 72.00 plus shipping (€ 12.00 within Germany / 

€ 14.00 outside of Germany). 

as an e-paper magazine (single user) 

at the annual price of € 72.00. 



(within Germany) / € 107.60 (outside of Germany) 

incl. shipping. 

Company/Institution 

First name, surname of recipient (department or person) 

Street/P.O. Box, No. 

Country, postalcode, town 

Reply/Antwort 

Readers’ Service gas for energy 

Postfach 91 61 

97091 Wurzburg 

GERMANY 

Phone 

E-Mail 

Line of business 

Fax 

Please note: According to German law this request may be withdrawn within 14 days after order date in writing 

to Readers’ Service gas for energy, P.O. Box 91 61, 97091 Wurzburg, Germany. After the first period the agreement can be 

terminated in writing with 2 months notice to the end of each year. In order to accomplish your request and for communication 

purposes your personal data are being recorded and stored. 

In order to accomplish your request and for communication purposes your personal data are being recorded and stored. 

It is approved that this data may also be used in commercial ways by mail, by phone, by fax, by email, none. 

This approval may be withdrawn at any time. 

✘ 

Date, signature 

PAGFE2014

EDITORIAL 

EU internal energy market – 

Challenge or illusion? 

Implementation of the internal energy market by 2014 – the EU 

likes to set itself targets. On the one hand, these are a good 

incentive to make progress. On the other hand, they bear the 

risk of hasty or incomplete action or of still being pursued even 

though practice and experience point to revision. 

Some Member States are lagging behind in the implementation 

of the Third Package on the internal electricity and gas 

markets, but large progress has nevertheless been made both 

in the transposition and the application of the laws. 

ACER, ENTSOG, the European Commission and the market 

participants have worked hard on the development of rules 

and network codes for cross-border gas transport. Not all but 

many of them will be adopted by 2014. Then they will be put to 

the test provided that Member States have duly implemented 

them. 

Hub trading has greatly increased. The Commission reported 

on the first quarter of 2013 that in the UK, the Netherlands, 

Belgium, Germany, France, Austria and Italy 80% of the gas 

consumed in these countries was delivered via hubs. On the 

second quarter, the Commission reported an increase in hubtraded 

volumes in Poland and the beginning of hub activities 

in Hungary. 

The retail market has seen a considerable rise in the number of 

suppliers, thus increasing the choice also for households. In 

some countries, the choice has become so wide that despite 

the availability of comparison tools (which are not always 

reliable) it is difficult to make a decision. 

So, what’s the problem? 

Firstly, the implementation of the Third Package in all Member 

States remains a challenge. The Commission helps and pushes 

with infringement procedures being the last resort. Additional 

rules and network codes need to prove practicable and efficient. 

They may require adaptation. 

Secondly, there are a number of counterproductive developments 

that hamper the market. For example, price regulation 

limits the fluctuation of prices and the natural mechanism of 

supply and demand. The wish for price stability often ignores 

the fact that a variable price can finally be a lower price. 

Subsidies are another counter-mechanism that can distort 

competition and prevent the market from developing the 

most cost-efficient solutions. 

Both price regulation and subsidies, in particular for renewable 

energy sources, have contributed to gas-fired power stations 

having become uneconomic 

in many countries. During 

peak periods or when 

the wind is not blowing 

or the sun not 

shining, they can 

be switched on 

Beate Raabe 

Secretary General 

of Eurogas

EDITORIAL 

flexibly. That is their selling point, but the dilemma in the face of 

distorted wholesale prices is clear. This is why in some countries 

the creation of capacity remuneration mechanisms are 

considered, i.e. the creation of incentives to keep otherwise uneconomic 

power generation capacity available for times of need. 

If market distortions cannot be removed or not quickly enough, 

capacity remuneration mechanisms can be an effective solution, 

but they should not themselves distort the market. 

The Commission has expressed strong concern and has recommended 

giving preference to demand-side response measures 

(electricity customers agree that certain appliances are 

switched off at certain times) and better interconnection of the 

Member States before resorting to capacity remuneration 

mechanisms. However, the question is whether the first two 

solutions are always the most cost-efficient solutions and 

whether all three options should not be considered at the 

same time. 

As regards climate protection, there have also been some counter-productive 

developments in recent years. The emissions 

trading system should have ensured that low-carbon energy 

has a cost advantage over high-carbon energy. However, due to 

the economic crisis and a lack of optimisation between different 

climate policies there is a surplus of allowances the price of 

which is currently around EUR 5 per tonne. This price is not a 

great incentive to invest in energy efficiency or low-carbon 

technologies. Moreover, large quantities of coal have become 

available in the United States who has been switching its power 

generation from coal to home-produced shale gas. These large 

amounts of coal are sold cheaply on the European market, 

which has led to the paradoxical situation that both the market 

share of renewable energy sources and coal have been rising in 

the EU and that of gas has gone down. Whilst carbon dioxide 

emissions dropped sharply in the U.S., they are rising again in 

some EU Member States, for example in Germany. 

All this highlights the efforts required to ensure that a wellfunctioning, 

low-carbon EU energy market is not an illusion, and 

to avoid that part of what has already been achieved is even 

lost. It is important that Member States recognise the need to 

adapt current policies and replace national regulation and subsidies 

with more competition and more Europe. This should be 

done as soon as possible because investors urgently need a 

clear and common political signal where EU policy is heading. 

Beate Raabe 

Secretary General of Eurogas

The Gas Engineer’s 

Dictionary 

Supply Infrastructure from A to Z 

The Gas Engineer’s Dictionary will be a standard work for all aspects of 

construction, operation and maintenance of gas grids. 

This dictionary is an entirely new designed reference book for both engineers 

with professional experience and students of supply engineering. The opus 

contains the world of supply infrastructure in a series of detailed professional 

articles dealing with main points like the following: 

• biogas • compressor stations • conditioning 

• corrosion protection • dispatching • gas properties 

• grid layout • LNG • odorization 

• metering • pressure regulation • safety devices 

• storages 

Editors: K. Homann, R. Reimert, B. Klocke 

1 st edition 2013, 452 pages with additional information and complete ebook, 

hardcover, ISBN: 978-3-8356-3214-1 

Price € 160,– 

DIV Deutscher Industrieverlag GmbH, Arnulfstr. 124, 80636 München 

www.di-verlag.de 

Order now! 


FUTURE 

Order now by fax: +49 201 / 820 02-34 or send in a letter 


Yes, I place a firm order for the technical book. Please send 

— copies of the The Gas Engineer’s Dictionary 

– Supply Infrastructure from A to Z. 

1st edition 2013, plus ebook (ISBN: 978-3-8356-3214-1) 

at the price of € 160,- (plus postage and packing extra) 




Country, Postalcode, Town 

reply / Antwort 

Vulkan-Verlag GmbH 

Versandbuchhandlung 

Postfach 10 39 62 

45039 Essen 

GERMANY 

Phone 

E-Mail 


Fax 


to Vulkan Verlag GmbH, Versandbuchhandlung, Postfach 10 39 62, 45039 essen, Germany. 



this approval may be withdrawn at any time. 


PATGED2013

TABLE OF CONTENTS 3 – 2013 

6 HOT SHOT 

Interior view of a fuel cell 

Reports 

10 TRADE & INDUSTRY 

Inspection of the Nord Stream 

Pipelines 

20 TRADE & INDUSTRY 

Shah Deniz Consortium announces 

25-year sales agreements with 

European gas purchasers 

GAS QUALITY 

26 Natural gas interchangeability in China: some experimental 

research 

by Y. Zhan and Ch. Qin 

GAS QUALITY 

36 Admissible hydrogen concentrations in natural 

gas systems 

by K. Altfeld and D. Pinchbeck 

GAS STORAGE 

48 Modern technical measurement concepts for the 

underground storage of natural gas 

by A. Zajc and M. Friedchen 

Columns 

1 Editorial 

6 Hot Shot 

70 Diary 

4 gas for energy Issue 3/2013

3 – 2013 TABLE OF CONTENTS 

26 R E P O R T 

Natural Gas interchangeability 

in China 

48 R E P O R T 

Technical measurement 

concepts for the underground 

storage of natural gas 

68 PRODUCTS 

Software package offers 

versatile product monitoring 

MICRO CHP 

54 Seven things you need to know about Micro-CHP 

in Europe 

by S. Dwyer 

BIOGAS 

58 Ensuring operational safety of the natural gas grid by 

removal of oxygen from biogas via catalytic oxidation of 

methane 

by F. Ortloff, F. Graf and Th. Kolb 

News 

visit us at our website: 


8 Trade & Industry 

22 Events 

24 Personal 

66 Associations 

68 Products & Services 

Issue 3/2013 gas for energy 5

HOT SHOT 



In a chemical reaction liquid or 

gaseous energy can be converted 

into electrical power. 

Source: DLR

TRADE & INDUSTRY 

Finngulf LNG 

included in the list of 

projects that may qualify 

for EU funding 

Bestobell secures 

major marine contract 

UK-based Bestobell Valves, part of the President 

Engineering Group (PEGL), has won a major new 

contract to supply cryogenic valves to TGE (Marine 

Gas Engineering) in Germany for two fuel-efficient 

dual-fuel cruise liners. 

The valves are destined for Mitsubishi Heavy 

Industries in Japan where the 984ft long vessels are 

being built, on behalf of Aida cruise lines of Germany. 

Aida’s new cruise ships will be able to run on LNG 

(liquefied natural gas), which offers greater fuel efficiency, 

as well as marine diesel oil or heavy fuel oil. 

Bestobell Valves will supply around 40 globe valves, 

non-return valves and check valves for the contract, 

which are currently being made at its factory in Sheffield 

ready to be shipped out to TGE in August this 

year for incorporation in their fuel system. 

T 

he list of Projects of Common Interest (PCI) 

adopted by the European Commission does not 

yet provide a final decision on whether Finland or 

Estonia will receive investment funding for a Gulf of 

Finland LNG import terminal. The final decision will 

be made with the EU-wide application process taking 

place in 2014, in which all the PCI-candidates are 

eligible to apply. Finland and Estonia are both seeking 

EU investment funding for a liquefied natural 

gas (LNG) import terminal. Both projects are 

included in the list of eligible projects published by 

the EU, but funding can only be granted to one of 

the projects. 

A condition set for EU financial support is that the 

terminal must serve multiple EU countries. The Balticconnector 

gas pipeline planned by Gasum will enable 

the interconnection of the Finnish and Baltic gas networks, 

which means the Baltic States would also benefit 

from the Finnish terminal. 

The Finngulf LNG terminal project and the Balticconnector 

gas pipeline comprise one of the largest 

infrastructure undertakings in Finland. The import terminal 

would increase diversity and flexibility in natural 

gas sourcing and enable new uses for natural gas outside 

the natural gas network. 

Granted PCI status, the Finnish and Estonian terminal 

projects can next apply for financial investment 

support in the Connecting Europe Facility (CEF) process 

covering all of Europe’s gas and electricity infrastructure 

projects and beginning in early 2014. Representatives 

of Gasum and the state of Finland will also 

continue negotiations to reach a compromise with 

Estonia. In this the countries could make a mutual 

decision on which one will proceed to the CEF application 

already by the end of this year. 

Gasum is making preparations for its own investment 

decision following the decision on EU financial 

support in late 2014. From there terminal construction 

would progress in phases, and LNG imports could 

begin in late 2016, which is when the Balticconnector 

would also be operational. The terminal would operate 

on full capacity at the end of 2018. 



WELTEC BIOPOWER 

develops 1.6 MW of green 

energy in France 

Together with the partner Domaix Energie in Alsace, 

the company from Germany has started rolling out 

four agricultural biogas plant projects in France. 

Apart from agricultural substrates, the biogas plants, 

whose construction has already started, will use sludge 

and food leftovers. This documents the trend that 

French biogas plants are increasingly fermenting industrial 

leftovers. Since the introduction of the separation 

and utilisation of kitchen waste from large catering 

establishments in France at the end of 2011, organic 

waste from schools and company cafeterias must be 

used for the production of energy. 

Accordingly, WELTEC will integrate hygienisation 

units in order to utilise the substances of category 3 

according to the EU directive. Another common feature 

concerns the use of the heat: In all four biogas plants, 

the residual heat will be used in a digestate dryer in 

order to reduce the amount of liquid manure and market 

the dried digestate. 

Thanks to the heat utilisation concept, the four 

biogas plants have an efficiency of at least 70 percent, 

enabling the operators to benefit from the heat and 

power bonus, which is up to € 0.04/kWh in France. 

11.-13.2.2014 

Essen /Germany 

DEVELOPMENTS AND TRENDS IN THE 

ENERGY INDUSTRY – DO YOU KNOW 

WHERE THE MARKET GOES? 

European Electricity Market European Electricity Grid 

International Gas Market Small Scale LNG 

Power Trading in Europe 

PROGRAMME AND REGISTRATION UNDER 

www.e-world-essen.com/congress 



Record-setting "PIG" run for the integrity inspection 

of the Nord Stream Pipelines 

Nord Stream has concluded a comprehensive inspection 

of the internal condition of both pipelines, as 

part of its long-term safety and pipeline integrity management 

strategy. 

A measurement tool about 7 m long and weighing 

more than 7 t was sent through the pipeline from Russia 

to Lubmin, Germany, travelling at 1.5 m a second propelled 

by the gas pressure. The pipeline inspection gauge 

(PIG) collected high-resolution data on material integrity 

along the 1,224 km route. The journey for Russia to Germany 

took ten days. 

This was the first time that a pipeline of this length and 

a wall-thickness of up to 41 mm has been analysed in this 

way. For the inspection run, a device with one of the 

strongest magnetic fields was developed by ROSEN Group 

in Lingen, Germany. The “intelligent PIG” has an array of 

electronic sensors, which screen the material integrity and 

the geometry of the pipeline. The PIG has collected over 

one Terabyte of data on its journey from Russia, and the 

data was recorded at a rate equivalent to 12 Megabits per 

second, 30 times faster than cellular data networks. 

The high-resolution measurement technology can 

detect smallest changes in the condition of the pipelines. 

The exact geographical position of the pipelines is also 

being documented. The first evaluation of the results 

confirms that the pipelines have moved only minimally 

while being operated under full pressure and that there 

has been no corrosion or deformation. 

In 2012 and early summer of 2013, Nord Stream had 

already examined the external condition of both pipelines. 

This external visual and instrumental inspection of 

the pipeline was conducted via remotely operated vehicles 

(ROVs) followed by support vessels. The results of the 

internal and external inspections form the baseline data 

for regular inspection cycles in the coming years. This will 

allow any potential changes in the position of the pipes, 

minimal corrosion and even the smallest mechanical 

defects to be detected at an early stage. 


19. EUROFORUM-Annual Conference 

4 to 6 December 2013, 

Kempinski Hotel Bristol Berlin – Germany 

gas 

Meet the decision makers of the 

European gas industry! 

A selection of the experts panel … 

The European Gas Market – 

Facing the current challenges in Europe! 

6 December 2013 

Ali Arif Aktürk, 

NaturGaz 

Klaus-Dieter Barbknecht, 

VNG – Verbundnetz Gas 

Rashid Al-Marri, 

South Hook Gas 

Peter Drasdo, 

Fluxys TENP 

• The structure of the European gas market – characteristics and specificities 

• Roadmap to a Single Gas Market in 2014: further steps 

• New sources – new routes – new partners for Europe 

• The importance of continuing investments in E&P 

• Development of trading markets and the supply & demand situation 

• The particular importance of LNG for the European Gas Market 

• The Future of L-Gas Network: is a new Policy necessary for Gas Trading? 

• One grid from Italy to Belgium – is this the transition to an independent super TSO? 

• The impact of the new market models 

• Emerging Gas Markets: how competition improves 

Presentations planned from the following countries: 

Hans-Peter Floren, 

OMV 

Bart Jan Hoevers, 

Gasunie Transport 

Ireneusz Łazor, 

Polish Power Exchange 

Jayesh Parmar, 

Baringa Partners 

Don´t miss the Pre Conference on 

The German Gas Market 

Angela Merkel‘s re-election: 

Implications for Germany‘s energy 

reform and the German gas market 

(Conference Language: German) 

Beate Raabe, 

Eurogas 

www.erdgas-forum.com/programme 

Infoline: +49 (0) 2 11/96 86–34 36 [Olivia Eberwein]


ista signs cooperation 

agreement with 

Spanish energy utility, 

Gas Natural Fenosa 

The energy service provider, ista, and the leading Spanish 

gas utility, Gas Natural Fenosa, have signed a 

cooperation agreement for the Spanish market. According 

to this agreement, ista will install 60,000 heat allocation 

meters in Gas Natural Fenosa properties and perform 

the meter-reading, billing and device management. 

The EU Energy Efficiency Directive (EED), which came 

into force at the end of 2012, is to be already transposed 

into national law by June 2014. The directive sets binding 

targets for the efficient use of energy, especially in the 

building sector, and prescribes, among other things, that 

consumers throughout Europe have to be informed individually 

and regularly about their energy consumption. 

Roughly 15 % of energy can be saved through the individual 

metering and billing of consumption data alone. 

Roughly 200 households in Germany currently receive 

monthly consumption data, which can be retrieved at any 

time online or using a smartphone, in Europe’s largest 

model project conducted in conjunction with Deutsche 

Energie-Agentur GmbH (dena – German Energy Agency), 

the German Tenant Organisation (DMB) as well as the Federal 

Ministry of Transport, Building and Urban Affairs. Initial 

results in early 2014 should once again prove that providing 

consumption information during the year can make a 

vital contribution to greater energy, CO 2 and cost efficiency, 

in particular with regard to the cost/benefit ratio. 

GDF SUEZ strengthens 

strategic partnership 

with Mitsui in Australia 

GDF SUEZ and Mitsui & Co., Ltd. (“Mitsui”) have 

agreed to strengthen their existing partnership in 

Australia. As part of the agreement, Mitsui will acquire a 

28 % equity interest in five assets from GDF SUEZ Australian 

Energy, a wholly owned subsidiary of GDF SUEZ. 

GDF SUEZ Australian Energy owns and operates 

3,540 MW of renewable, gas fired and brown coalfired 

generating units in Victoria, South Australia and 

Western Australia. 

Both companies already have a strong, long-term 

partnership following a successful track record of joint 

investment and cooperation for projects in Canada, 

Europe, the Middle East, Africa, Asia as well as an existing 

partnership agreement in Australia, where Mitsui 

has owned 30 % of the Loy Yang B power station and 

21 % of Kwinana power station since 2004. This transaction 

will extend the existing partnership with Mitsui 

to the entire Australian portfolio. 

The transaction, which comprises four, principally 

merchant, assets with a total capacity of 2,463 MW 

and the Simply Energy retail business, will create a 

common ownership platform across the Australian 

generation asset portfolio. 

This new partnership, which is in line with the 

Group’s transformation strategy, will contribute to the 

Group’s 2013-14 portfolio optimisation program and will 

lead to a reduction in the Group’s net debt upon completion 

of the transaction, which is expected this month. 

Prysmian Group signs major contracts 

with Brazilian Petrobras 

Prysmian Group has been awarded new major contract 

worth a total of up to approximately $ 260 Million 

related to a frame agreement for Umbilical products 

for offshore oil and gas extraction, by Brazilian oil company 

Petrobras. 

The award refers to a frame agreement for 360 km of 

Umbilicals, most of it to be used in pre-salt fields, in 16 

different cross sections and related ancillaries, offshore 

services and qualifications, worth approximately $ 260 

Million with 50 % minimum purchasing commitment and 

call-off orders to be placed within a two-year period. 

The Group has also been awarded by Petrobras the 

extension to 2016 of the existing frame agreement for 

flexible pipes, worth a total of $ 95 Million of which $ 20 

Million have already been called off for the Macabu, 

Jubarte and Marlim Leste fields. 

Both the Umbilicals and the Flexible Pipes for the new 

contracts will be manufactured in the Group’s state-ofthe 

art- plants in Vila Velha, Brazil, an industrial plant with 

high production capacity and a strategic location (on the 

Vitoria channel - Espirito Santo State) fully dedicated to 

Subsea Umbilicals, Risers and Flowlines (SURF). 



Bilfinger automates power-to-gas pilot 

plant for E.ON 

Bilfinger is responsible for automation technology at 

the Falkenhagen power-to-gas pilot plant, which 

E.ON will use to feed hydrogen into the natural gas 

grid for the first time. The automation solution installed 

by subsidiary Bilfinger GreyLogix ensures that the plant 

is operational around the clock and monitors the volume 

of hydrogen being fed into the grid. 

The pilot converts up to two megawatts of 

electrical output to hydrogen per hour and subsequently 

feed it into the natural gas grid. With this 

project, E.ON hopes to gain further expertise in 

the storage of regenerative gas in the natural gas 

infrastructure. With such expertise, it is possible to 

store over-capacity from fluctuating renewable energy 

sources and to access it when needed. 

In order to tap into new technologies and markets, 

research and development efforts have been intensified. 

As lead investor, Bilfinger supports the young 

start-up company Sunfire from Dresden. Sunfire 

develops concepts for using renewable energy to 

convert carbon dioxide and water into fuel (power-toliquids) 

or gas (power-to-gas). 

14 – 16 JANUARY 2014 

NUREMBERG, GERMANY 

· World’s largest BIOGAS trade fair 

· 3 days with plenary sessions, workshops, best-practice 

· Excursions 17 January 2014 

Main Topics: 

· Biogas as a part of the energy turn around 

· Trends in the construction of biogas plants 

· New challenges in environmental and safety issues 

· International: The future of export business 

Main speaker Prof. Dr. Claudia Kemfert, (DIW Berlin) 

News: www.biogastagung.org/en 

23 rd CONVENTION AND TRADE FAIR 

www.biogastagung.org 

www.biogastagung.org 

Issue 3/2013 gas for energy 13 

Biogas kann´s 

Fit für die Zukunft 

Biogas can do it


Aid for investment projects of GAZ-SYSTEM S.A. 

The European Commission declared compatible with 

the Treaty on the Functioning of the European Union 

individual aid for GAZ-SYSTEM S.A. for the implementation 

of the following tasks: 

■■ 

■■ 

■■ 

■■ 

■■ 

■■ 

Hermanowice – Strachocina Gas Pipeline, 

Strachocina – Pogórska Wola Gas Pipeline, 

Zdzieszowice – Wrocław Gas Pipeline, 

Skoczów – Komorowice – Oświęcim Gas Pipeline, 

Modernisation of the transmission system in Lower 

Silesia in order to improve its functioning and to 

ensure the optimal use of the Polish-German interconnection, 

Lwówek – Odolanów Gas Pipeline. 

A potential award of subsidies from the European 

Regional Fund will be possible in case of the availability 

of funds within the “Infrastructure and Environment” 

Programme. The investment projects are on the reserve 

list of individual projects of the “Infrastructure and Environment” 

Programme. Expected support from the European 

funds for the implementation of subsequent 

investment projects of GAZ-SYSTEM S.A. constitutes 

public aid in the meaning of Article 107.1 of the Treaty 

on the Functioning of the European Union. The total 

amount of such aid may amount to PLN 1,949.57 million, 

assuming the aid intensity at the level of 45.67%. 

The above mentioned projects are to be implemented 

in the years 2013–2020 as the elements of the North-South 

Gas Corridor. The prepared investment projects will contribute 

to the development of the Polish gas transmission 

system. They will affect the effectiveness of the system by 

increasing its transmission capacity, at the same time ensuring 

a higher security of supplies. In addition, the implementation 

of the above mentioned six investment projects also 

constitutes a significant input in promoting strategic objectives 

of the EU energy policy, such as: development of the 

basic infrastructure necessary for the functioning of the 

internal market of natural gas, increased security of supplies 

and diversification of sources, and the development of 

interconnections between Member States. 

GAZ-SYSTEM S.A. finances up to 30 % of its investment 

expenditures from the EU funds. 

OMV and Montanuniversität Leoben 

expand cooperation 

The oil and gas company OMV and Montanuniversität 

Leoben/Austria announced that are expanding 

their existing cooperation and working together 

on introducing a new degree program – the International 

Petroleum Academy. OMV is doubling investment 

in research and teaching. The Petroleum Academy 

will increase student numbers and facilitate a 

more international pool of graduates. The next three 

years will see OMV’s annual investment in the university 

increase to around 10 mn €. 

OMV launched a job initiative in July 2013, as the 

company’s growth plans will require an additional 1,600 

technical employees for the exploration and production 

of oil and gas by 2016. There is strong demand for petroleum 

engineering and geosciences graduates in addition 

to experienced experts. 

NDT Systems & Services opens pipeline 

inspection data analysis center in Mexico City 

NDT Systems & Services, a leading supplier of ultrasonic 

pipeline inspection and integrity services, 

announces the opening of its Global Data Analysis 

Center in Mexico City, Mexico. 

The new operational unit will serve as the company's 

global hub for analysis of pipeline data gathered by pipeline 

inspections worldwide. A team consisting of more 

than 50 analysts will analyze inspection data that are predominantly 

captured with ultrasonic technology, which 

is used to detect corrosion or cracks in liquid pipelines. 

Quality control and report production will be maintained 

at NDT sites in the US, Germany, Malaysia and Dubai. 



Wintershall takes over 

Brage operatorship 

Gazprom and 

Vietnam strengthening 

long-term partnership 

As part of Gazprom's delegation visit to Vietnam, Alexey 

Miller, Chairman of the Gazprom Management Committee 

held a working meeting with Nguyen Tan Dung, Prime 

Minister of the Socialist Republic of Vietnam. 

The parties discussed the prospects for interaction 

between Gazprom and Petrovietnam Oil and Gas Group in 

joint projects for oil and gas resource development offshore 

Vietnam and in the Russian Federation.The parties highly 

evaluated the work done by the companies in relation to 

launching commercial gas production from the fields of 

licensed blocks 05.2 and 05.3 offshore Vietnam. 

In addition, the meeting emphasized the importance 

of the Agreement signed by Gazprom and Petrovietnam 

on establishing a joint venture for implementing the project 

on natural gas use as a vehicle fuel in the Republic of 

Vietnam. 

The meeting addressed the agreements reached by 

Gazprom and Petrovietnam for speeding up the negotiating 

process surrounding liquefied natural gas supplies to 

Vietnam within the Vladivostok-LNG project and the intention 

to sign a Framework Agreement concerning LNG supplies 

before the end of 2013. 

Summarizing the results of the negotiations, Alexey 

Miller and Nguyen Tan Dung confirmed their commitment 

to strengthen the mutually beneficial long-term 

partnership. The parties shared the opinion that the companies' 

interaction in Vietnam and Russia had a high 

development potential. 

W 

intershall Norge is taking over the operatorship 

of the Brage oil field on the Norwegian 

Continental Shelf (NCS) from Statoil. The Brage 

platform off Bergen is the first major production 

platform operated by Wintershall Norge. Since the 

transfer of equity in the fields Brage, Gjøa and Vega 

to the wholly owned BASF subsidiary at the end of 

July as part of the asset swap with Statoil, Wintershall 

Norge has raised its daily production from 

3,000 boe to 40,000 boe. The asset swap thus 

turned Wintershall into a major producer on the 

NCS. With the operatorship of Brage, Wintershall 

now executes the complete E&P lifecycle in Norway: 

from exploration, drilling and the development 

of oil and gas discoveries to production. 

Looking at 

the big picture 

Seminar Flow 

Metering in Pipelines 

on 25. March 2014 

In cooperation with 

7th Workshop 

Gas Flow Measurement 

Industrial gas application 

26./27. March 2014 · KCE-Akademie, Rheine 

Seminar, workshop and documents are in German language. 

Application and further information: 

www.kce-akademie.de 

KÖTTER Consulting Engineers GmbH & Co. KG 

Bonifatiusstraße 400 • D-48432 Rheine • Germany 

Tel.: +49 5971 9710-0 • E-Mail: info@koetter-consulting.com 



Gas discovery in Iskrystall 

Statoil ASA has together with its partners Eni Norge AS and 

Petoro AS made a gas discovery in the Iskrystall prospect 

in PL608 in the Barents Sea. Well 7219/8-2, drilled by the drilling 

rig West Hercules, has proved an approximately 200 metre gas 

column. Statoil estimates the volumes in Iskrystall to be 

between 6 and 25 million barrels of oil equivalents (o.e.). 

Iskrystall was the second of the four prospects to be 

drilled in the Johan Castberg area this year with the aim 

of proving additional volumes for the Johan Castberg 

field development project. The first prospect Nunatak 

resulted in a small gas discovery. 

A comprehensive data acquisition program was performed 

in the Iskrystall well including coring, wire line 

logging and fluid sampling. This gives valuable geological 

information about the Johan Castberg area. 

Statoil and the partners in the Johan Castberg project in 

the Barents Sea decided in June 2013 to delay the investment 

decision for the project to further mature the resource base 

and field development plans for the project. In addition there 

are uncertainties in the tax frame work for the project. It is 

necessary to conclude the remaining exploration wells and 

ongoing work on field development plans, until the partners 

are ready to make an investment decision for the project. 

After completion of Iskrystall, the West Hercules rig 

will move back to the production license 532 to drill the 

Skavl prospect. Skavl is situated approximately 5 km 

south of the Skrugard discovery (now part of Johan Castberg). 

Statoil is operator for production licence 608 with 

an ownership share of 50%. The licence partners are Eni 

Norge AS (30%) and Petoro AS (20%). 



Ukrainian gas pipe 

among EU’s Key energy 

infrastructure projects 

A 

project involving Ukrainian gas transport system has 

made it to the list of 250 key energy infrastructure 

projects, adopted by the European Commission on October 

14, 2013. The projects will receive funding of € 5.85 

billion during 2014-2020. Financing these energy infrastructure 

projects would create most benefits to European 

consumers, according to EU Energy Commissioner 

Günther Oettinger. 

Ukrainian energy infrastructure project will involve 

the construction of a connecting Adamowo-Brody pipeline. 

It will extend for 371 kilometers joining the JSC 

Uktransnafta’s Handling Site in Brody (Ukraine) and Adamowo 

Tank Farm (Poland). The pipeline’s maximum technical 

capacity will reach 10, 20 and 30 million tonnes per 

year, respectively – "depending on the three consecutive 

stages of the project implementation." 

The completion of the 250 projects will help the EU members 

"integrate their energy markets, enable them to diversify 

their energy sources and help bring an end to the energy isolation 

of some Member States," reads the europe.eu note. Moreover, 

the projects will "enable the energy grid to uptake increasing 

amounts of renewables," helping reduce CO 2 emissions. 

Ukraine is a major transporter of imported Russian gas to 

Europe. Its vast pipe network (nearly 40,000 kilometers long) 

allows the country to transport, store, and distribute gas to 

many European countries. Ukraine’s pipelines go from Russia 

to Belarus, Hungary, Moldova, Poland, Romania, and Slovakia. 

Ukraine obtained its first gas pipe back in 1924. Its gas transport 

infrastructure has been developing rapidly ever since. 

Presently, Ukraine possesses 13 underground gas storage 

facilities with total capacity of more than 31 billion 

cubic meters, reports epravda.com.ua. 

WINGAS and E.ON bring 

highly efficient natural gas 

CHP plant on stream 

WINGAS and E.ON Energy Projects brought the new, 

highly efficient combined heat and power (CHP) 

plant in Lubmin on stream. The CHP plant, located right at 

the landing terminal of the Nord Stream Baltic Sea pipeline, 

has a useful heat output of about 47 MW and an electrical 

output of about 39 MW. The plant generates up to 200,000 

MW hours of electricity a year – enough to provide a 

secure supply for 50,000 households for a whole year. 

A highly efficient gas turbine developed by Siemens is 

being deployed in Lubmin for the first time. It allows the 

plant to reach full load capacity in just ten minutes. 

Lubmin, a central energy hub, offers ideal conditions for 

the construction of a natural gas-based CHP plant thanks 

to the existing infrastructure; the Baltic Sea pipeline delivers 

a reliable supply of natural gas right there. In addition, 

the waste heat generated in the gas turbine is used to 

reheat the gas, which cools down while traveling through 

the Baltic Sea pipeline, before its onward transportation 

over land. With the combined generation of electricity and 

heat, the overall efficiency of the plant is over 85%. This 

means that the Lubmin CHP plant saves around 40,000 

tons of CO 2 a year compared to the separate generation of 

heat and electricity – that is as much as 13,000 cars a year. 

South Stream designing in Slovenia to be sped up 

The Gazprom headquarters hosted a working meeting 

between Alexey Miller, Chairman of the Company's Management 

Committee and Samo Omerzel, Minister of Infrastructure 

and Spatial Planning of the Republic of Slovenia. The 

parties discussed issues concerning the current status of 

cooperation between Russia and Slovenia in the gas sector. 

Special attention was paid to the South Stream project 

implementation in the Republic of Slovenia. At present, 

the work is nearing completion on the spatial planning 

and environmental impact assessment (EIA) procedures 

conducted under the national laws of Slovenia for 

the gas pipeline sections from the boarders with Hungary 

and Italy. The meeting resulted in the decision to 

speed up the designing of the Slovenian section of the 

gas pipeline carried out by the South Stream Slovenia 

LLC joint company. 


CEB® 

... Think Future 

March 6 th — 8 th , 2014 

Trade Fair Center 

Stuttgart 

Trade Fair and Conference for... 

Energy efficient 

Building 

Technical 

building equipment 

Regenerative 

energy production 

www.ceb-expo.de


Shah Deniz Consortium announces 25-year sales 

agreements with European gas purchasers 

The Shah Deniz consortium announced that 25-year 

sales agreements have been concluded for just 

over 10 billion cubic metres a year (BCMA) of gas to be 

produced from the Shah Deniz field in Azerbaijan as a 

result of the development of Stage 2 of the Shah Deniz 

project. Nine companies will purchase this gas in Italy, 

Greece and Bulgaria. 

The Shah Deniz Stage 2 project is set to bring gas 

directly from Azerbaijan to Europe for the first time, 

opening up the Southern Gas Corridor. In total 16 BCMA 

of Shah Deniz Stage 2 gas will be delivered through 

more than 3500 km of pipelines through Azerbaijan, 

Georgia, Turkey, Greece, Bulgaria, Albania and under the 

Adriatic Sea to Italy. The agreements for European gas 

sales follow the signing of agreements with BOTAS in 

2011 to sell 6 BCMA of gas in Turkey. 

The buyers who have agreed to buy the gas are: 

Axpo Trading AG, Bulgargaz EAD, DEPA Public Gas Corporation 

of Greece S.A., Enel Trade SpA, E.ON Global 

Commodities SE, Gas Natural Aprovisionamientos SDG 

SA, GDF SUEZ S.A., Hera Trading srl and Shell Energy 

Europe Limited. Of the total 10 BCMA, around 1 BCMA 

will go to buyers intending to supply to each of Bulgaria 

and Greece and the rest will go to buyers intending to 

supply Italy and adjacent market hubs. 

The completion of these agreements follows 

expressions of interest from many different companies 

for Shah Deniz gas and marks the completion of the 

Shah Deniz 2 gas sales process. The gas sales agreements 

will enter into force following the final investment 

decision on the Shah Deniz Stage 2 project 

which is targeted for late this year. 



Marketing of natural gas 

storage facility Inzenham-West 

concluded 

RWE Dea Speicher GmbH (RDS) has successfully 

marketed the entire working gas capacity of its 

natural gas storage facility Inzenham/West near 

Rosenheim, Bavaria, for the years 2014 to 2016. The 

Inzenham-West storage facility and its new customers 

will therefore continue to make an essential 

contribution to supply security in Bavaria. 

Based on a broad market appeal and constructive 

talks with various interested parties, RWE Dea Speicher 

GmbH (RDS) managed to successfully conclude 

the marketing activities for its storage facility at Inzenham-West. 

In the process, the entire working gas 

capacity of 4,625 MWh was fully placed on the market 

for the next storage years 14/15 and 15/16. For a further 

eight years, it was possible to sell nearly half of 

the storage volume on a long-term basis. 

British Gas and Landis+Gyr 

announce Smart meter deal 

British Gas customers are set to benefit from a £600m 

deal between British Gas and Landis+Gyr. The landmark 

deal means Landis+Gyr will supply the majority of 

the 16 million smart meters British Gas will install in its 

customers’ homes. 

By 2020 smart meters will be rolled out as standard to 

homes and businesses across the country as part of a 

Government initiative. They will replace current gas and 

electricity meters and offer the benefits of: 

■■ 

■■ 

■■ 

An in-home display showing how much gas and electricity 

is being used as customers are using it – and 

the cost in pounds and pence 

Estimated savings of around 5% (£65) per year 

Meter readings sent directly to energy suppliers, putting 

an end to estimated bills 

British Gas adopted a strategy to introduce smart meters 

into homes and businesses early in order to bring these 

benefits to customers as soon as possible. 

THE BEST PROTECTION 

FOR A LIFETIME 

Admittedly, we 

copied from nature … 

DEKOTEC ® 

Heat Shrink 

Sleeve 

DENSO is the inventor of the PETROLATUM Tape in the 1920‘s. Original DENSOLEN ® Tapes 

and Tape Systems, DENSOLID ® -Polyurethane Coatings and DEKOTEC ® Innovative Hotmelt and Mastic 

… to create the best 

protection for you! 

Find out more: 

denso.de 

Shrink-Sleeve Technology. Leader in Innovation since more than 90 years. Made in Germany. 

DENSO GmbH 

Felderstraße 24 

Member of: 

Certified by: 

51371 Leverkusen | Germany 

A Member of 

Denso Group Germany - 

+49 214 2602-0 

MEMBER OF 

Denso Group 

Germany 

The Inventor Issue 3/2013 of Passive gas for energy +49 21214 2602-217 

dekotec.net 

Corrosion Prevention 

sales@denso.de 

® 

Certified 

DIN EN ISO 9001

EVENTS 

Annual Balkans Oil & Gas 2013 

IRN held the 2 nd Annual Balkans Oil & Gas 2013 Summit on 

24 th -25 th September in the Hotel Grande Bretagne in Athens, 

with key executives of the oil and gas industry giving 

insights and revealing future plans of the Balkans countries. 

With more than 100 companies attending the summit 

and an outstanding panel of speakers, IRN gathered their 

excellences Alen Leveric, Deputy Minister of Economy in 

Croatia, Vladan Dubljevic, Deputy Minister for Mining and 

Geological Researches at the Ministry of Economy in Montenegro 

and Konstantinos Mathioudakis, General Secretary of 

Energy and Climate Change at the Ministry of Environment, 

Energy & Climate Change in Greece along with the Chairman 

& CEO of Energean Oil and Gas, Mathios Rigas, the CEO 

of Bulgartransgaz, Kiril Temelkov, the President & CEO of 

Stream Oil & Gas, Dr. Sotirios Kapotas and many other exploration 

directors in Balkans such as Max Torres from Repsol. 

Held under the auspices of the Ministry of Economy in 

Montenegro, the Ministry of Environment, Energy & Climate 

Change in Greece, the Ministry of Economy in Croatia 

and the Federal Ministry of Energy, Mining and Industry in 

Bosnia & Herzegovina, the event gathered the elite of Balkans 

businessmen, international energy experts, economists 

and senior representatives from more than ten IOCs 

looking to get investment in the upcoming developments. 

Gastech student programme application process now open 

The Gastech Student Programme 2014 is now welcoming 

applications from prospective candidates to participate 

in the 2014 programme. Designed to facilitate potential 

careers in the gas industry, the student programme will take 

place on 25 March 2014 running within the Gastech Conference 

& Exhibition from 24-27 March 2014 in KINTEX 1, Korea. 

Established in 2006, the Gastech Student Programme 

offers 60 university students from around the world, with 

the opportunity to receive an introduction into the natural 

gas sector and to learn about the career opportunities 

available to them, first hand from senior industry figures. 

The Programme is engineered to provide attendees 

with a thorough overview of the industry, focussing on 

global Gas & LNG markets, LNG Projects, Shipping and 

Contracts. Interactive elements include a Problem Solving 

Exercise, encouraging students to troubleshoot in 

small groups and present their findings. 

Previous participants in the Gastech Student Programme 

have spoken highly of their experience and of the valuable 

insight into the industry that the programme has provided them. 

Pipeline Technology Conference moves to Berlin 

To be eligible to take part in the Student Programme, 

prospective candidates must be: 

■■ 

In their final year of studying or in their first year since 

graduating 

■■ 

Must not have prior experience of working in the 

industry (unpaid internships are acceptable) 

■■ 

Students must not have any employment or internships 

already lined up 

■■ 

Post graduates are welcome to apply as long as they 

do not have prior industry experience 

■■ 

Must not have attended a previous Gastech Student 

Programme 

Candidates are required to summarise in no more than 

500 words, why they should be selected to attend the 

Gastech 2014 Student Programme and what they hope 

to both contribute and gain from the experience. 

The official closing date for the Gastech Student Programme 

application process is November 2013. 

More information about the Gastech Student Programme: 

www.gastechkorea.com/studentprogramme 

Having grown up as part of 

HANNOVER MESSE, Europe’s 

leading pipeline conference and 

trade show, Pipeline Technology 

Conference (ptc), will move to the 

capital Berlin next year. 

The ptc has grown steadily over the years and, in addition 

to the conference itself and the accompanying exhibition, 

it is now also directly followed by several special 

workshops and in-depth seminars. International participants 

from over 30 different countries use the opportunity 

to come to Europe and obtain information about 

cutting-edge technologies and new pipeline projects. 

The ptc 2014 will take place from May 12-14, 2014 in 

the Convention Center of the Estrel Berlin and, in addition 

to the usual topics, will focus specifically on the areas of 

onshore and offshore construction and pipeline safety. 

More information on participating in the event as a 

speaker, visitor or exhibitor, can be found at www.pipeline-conference.com. 


EVENTS 

E-world 2014 

How is the energy market in Europe developing? 

That will be one of the central questions at the 

E-world Congress 2014 which will take place at Messe 

Essen on February 11 - 13, 2014 parallel to the premier 

European fair, E-world energy & water. In 25 conferences, 

international experts from the political and 

economic fields will provide information about topical 

questions in the sector. Because the markets are coming 

closer together, ever greater consideration is focusing 

not only on the national electricity and gas supply 

but also much more on the European electricity and 

gas supply as a whole. High-ranking representatives of 

the European Commission will also examine the future 

of these supply grids within the framework of the congress. 

Moreover, the congress will provide the housing 

industry with its own conference for the first time. The 

main subjects will be energy-related building renovation 

as well as energy procurement. 

In cooperation with Süddeutsche Zeitung ("South German 

Newspaper"), the "Energy Industry Leadership 

Meeting" already on the day before the fair (February 

10, 2014) will examine options for the strategic setting 

of the points for the energy world of tomorrow. Three 

central ideas will characterise the programme of lectures: 

"Fresh Wind for the Energy Turnaround", "Germany 

as a European Energy and Economic Location" as 

well as "Regulatory Perspectives for Creating International 

and National Infrastructures". The speakers will 

include Hannelore Kraft (Minister-President of North 

Rhine-Westphalia), Andreas Mundt (President of Bundeskartellamt 

- "Federal Cartel Office"), Dr. Frank Mastiaux 

(Chairman of the Board of EnBW AG) as well as 

Prof. Dr. Claudia Kempfert (Energy Market Expert at 

Deutsches Institut für Wirtschaftsforschung - "German 

Institute for Economic Research"). 

EnergieAgentur.NRW ("North Rhine-Westphalia 

Energy Agency") will once again stage the 18 th Expert 

Congress on "Future Energies" in cooperation with the 

EnergieRegion.NRW ("North Rhine-Westphalia Energy 

Region") and EnergieForschung.NRW ("North Rhine- 

Westphalia Energy Research") clusters. Topical specialist 

subjects from the area of future energies will be on the 

agenda at the all-day congress on the first day of the fair 

(February 11, 2014). After the opening by Johannes Remmel 

(North Rhine-Westphalia Minister of Climate Protection), 

the plenary session in the morning will offer lectures 

about trends, markets and new developments. Five 

parallel forums will take place in the afternoon. 

The conference entitled "European Electricity Market" 

will also take place on the same day. It will examine 

the development status of a uniform internal electricity 

market in the European Union, as Günther Oettinger (EU 

Energy Commissioner) proposed in 2011. In this respect, 

the lecture delivered by Prof. Dr. Klaus-Dieter Borchardt 

(Director of the Internal Energy Market Division of the 

European Commission) will certainly be particularly 

interesting for the sector. The conference will be compered 

by Dr. Roman Dudenhausen (Chairman of 

con|energy ag, Essen). 

High-ranking European experts will be expected 

also on the occasion of the conference called "International 

Gas Market" on the second day of the fair (February 

12, 2014). For example, Philip Lowe (Director-General 

for Energy at the European Commission) will 

explain what role gas will play in the future planning of 

the EU's energy policy. In this context, Prof. Jonathan 

Stern from the Oxford Institute for Energy Studies will 

explain the future role of Russia for the European gas 

supply. On the other hand, Dr. Friedbert Pflüger (Director 

of the Centre for Energy and Resource Security - 

EUCERS, London) will examine the significance of shale 

gas for the energy reliability in Europe. 

The conference entitled "Small-Scale LNG" will be 

dedicated to the trend subject of liquefied natural gas 

(LNG). For example, this will deal with the question of 

whether liquefied natural gas can be treated as a fuel 

alternative to oil and with efficient solutions for transport. 

Keynote lectures will be given, amongst others, by 

David Graebe (Head of Gas for Transport at Gazprom 

Germania), Ulco Vermeulen (Director of Business Development 

and Participations at Gasunie) as well as Nilgün 

Parker from the Federal Ministry of Transport, Building 

and Urban Development. 

In 2014, a purely scientific conference with the title of 

"SmartER Europe" which will be staged together with the 

University of Duisburg Essen will also take place for the first 

time. In the three main areas of "Energy Economics", "Energy 

Informatics" and "Energy Techniques", researchers and scientists 

should exchange their opinions about topical research 

subjects on the third day of the fair (February 13, 2014). 

www.e-world-essen.com/kongress/programm/ 


PERSONAL 

Fine Tubes welcomes Graham Maxa 

as new finance director 

Fine Tubes announces 

the appointment of 

Graham Maxa as the 

company’s new Finance 

Director. 

Based at Fine Tubes’ 

Head Office in Plymouth, 

Graham will have 

a key role to play in 

helping to drive the 

company forward following 

last year’s 

change of ownership. In particular, he will have specific 

responsibility for the financial direction of the 

company’s strategic plans in addition to maintaining 

day-to-day financial controls. 

A member of the Chartered Institute of Management 

Accountants, Graham has over 20 years’ experience 

with a wide range of manufacturing and engineering 

companies. Most recently he held the position 

of Group Financial Controller at Prodrive, the 

specialist engineering and motorsport company with 

headquarters in Oxfordshire and operations across 

the UK as well as in Australia. 

Wim Groenendijk as 

GLE president 

T 

he GLE members unanimously elected Wim 

Groenendijk, Vice-President International & Regulatory 

Affairs, N.V. Nederlandse Gasunie, as GLE President. 

Wim Groenendijk has been a member of the 

ENTSOG Board during its first term (2010-2012) and 

has been a member of the GIE Board since 2011. The 

election of Wim Groenendijk has coincided with decisions 

on further support of the European small scale 

LNG development. GLE members agreed to develop 

a map showing the small scale LNG infrastructure in 

Europe. The map will support the Clean Power for 

Transport package from the European Commission 

not only by showing existing small scale LNG infrastructure 

and projects but also by identifying missing 

links in the network. In addition to the transport sector, 

the study shall support the development of the 

use of LNG in off pipeline locations. The map shall be 

available by the end of 2013 and DNV (Det Norske 

Veritas BV) was awarded the contract. 

The scope of work of the GLE small scale LNG 

map is accessible at: http://www.gie.eu/index.php/ 

news/gle-news 

The GLE position paper ‘Overcoming barriers in 

the Small Scale LNG development’ is available at: 

http://www.gie.eu/index.php/publications/gle 

Johanna Lamminen 

appointed executive vice 

president at Gasum 

Johanna Lamminen, CEO of Danske Bank Plc, has been 

appointed Executive Vice President and Chief Financial 

Officer at Gasum. She took up the post on 1 September 

2013. Gasum’s CEO Antero Jännes will continue in his present 

post until the end of February 2014, when he will 

retire according to the terms of his service contract. 

Johanna Lamminen has long experience within the 

finance sector. In addition to having worked for Danske 

Bank, she has also worked for Evli Bank and for other companies 

in economy, finance and organisational development 

positions. 

Johanna Lamminen holds a Licenciate in Science 

(Technology) from Tampere University of Technology 

and completed an MBA degree in 1999. 


PERSONAL 

Appointments 

to the supervisory 

board of Gasunie 

Martika Jonk, partner at CMS Derks Star Busmann, 

Amsterdam, and Willem Schoeber, member of 

the Management Board of EWE AG, Oldenburg, 

Germany until 1 June 2013, have been appointed 

members of the Supervisory Board of Gasunie with 

effect from 1 October 2013. 

It was previously announced that with effect from 

1 January 2014, Hans Smits, CEO of the Port of Rotterdam 

Authority until 1 January 2014, will join the 

Supervisory Board of Gasunie in the role of chairman. 

With the announcement of these appointments, 

the Supervisory Board will consist of the following 

individuals from 1 January 2014: 

■■ 

■■ 

■■ 

■■ 

■■ 

■■ 

Hans Smits, chair 

Rinse de Jong 

Martika Jonk 

Jolanda Poots-Bijl 

Dr. Willem Schoeber 

Jean Vermeire 

Managing director of ONTRAS 

Uwe Ringel appointed as 

new co-chair of the PTC 

Uwe Ringel will succeed Heinz Watzka as cochair 

of the Pipeline Technology Conference. 

He started his professional career in 1984 as 

Engineer for gas supply technology (FH; University 

for Applied Science) within the Dispatching 

Department of the present VNG – Verbundnetz 

Gas AG, Leipzig. Since 1990 Ringel worked in the 

Gas Purchase Department. 2002 he changed into 

the Gas Transmission Department where he was 

the responsible Director from 2004 to 2005. 

Since January 2006 Uwe Ringel was Managing Director of 

the Network Marketing Department in the newly established 

network company ONTRAS Gas Transport GmbH, Leipzig. In 

2008 he moved within the group to VNG AG as Head of 

Technology/Operations. Since May 2010 Uwe Ringel is the 

Managing Director of the Technology Division of ONTRAS. 

Ringel is also Member of the Board of the German 

DVGW Deutscher Verein des Gas- und Wasserfaches e. V., 

Regional Group of Middle Germany. 

GIE appoints Thierry Deschuyteneer 

as new executive secretary 

The GIE Board has appointed Thierry Deschuyteneer as 

new GIE Executive Secretary as of 1 October 2013. Thierry 

Deschuyteneer has worked for more than 10 years for Fluxys 

in technical and regulatory departments. In this function he 

followed closely the European regulatory developments and 

European energy policy initiatives. During the last 3 years, he 

chaired the GIE Communication & Strategy Task Force and 

acted as Vice-Chair of the GasNaturally initiative. 

Hans-Joachim Polk new managing director of RWE Dea UK 

Hans-Joachim Polk is the new Managing Director of 

RWE Dea UK. Polk joined RWE Dea AG as early as late 

1991, immediately after earning his Master's degree in crude 

oil and natural gas exploration and production technology 

at Clausthal-Zellerfeld University. In the course of his professional 

career, Polk spent three and a half years working for 

RWE Dea in Cairo before returning to Germany, where he 

was responsible as Head of Operations for production from 

Germany’s largest oilfield, Mittelplate and as Senior Vice 

President Field Development RWE Dea. In the past 2 years 

as Managing Director of RWE Dea Norge, Polk optimised 

the licence portfolio and intensified exploration 

activities in Norway. It was possible to achieve 

major oil and gas strikes during this period. 

Polk is successor to René Pawel who will be 

relocating to RWE Dea’s Headquarters in Hamburg 

as Senior Vice President for Production in Europe. 

With immediate effect, Pawel will be responsible 

for the entire operations in Germany, Denmark, 

Norway, and the United Kingdom. The scope of his 

activities comprises both the production of crude 

oil and natural gas as well as the storage of gas. 


REPORTS 

Gas quality 

Natural gas interchangeability 

in China: some experimental 

research 

by Yangjun Zhang and Chaokui Qin 

Because of the difference between gas appliances in current China market and those research targets many 

years ago, the well-established index- and diagram-based methods to predict interchangeability cannot be 

taken as applicable to natural gases from different sources. 9 cookers and 6 water heaters were sampled and 

tested to evaluate response to varying constituents. Some efficiency and CO emission changes were observed. 

Results suggested further theoretical analysis and criterion be required to quantitatively define gas 

interchangeability. 

1. INTRODUCTION 

Natural gas industry in China witnessed unprecedentedly 

rapid development in past 15 years. By the end of 

2011 overall natural gas consumption increased to 108 

billion cubic meters (BCM) annually from 24.5 BCM in 

2000 [1]. The large-scale development of gas industry in 

China dated back to late 1990s when the first transmission 

gas pipeline was put into operation in 1997, carrying 

3.6 BCM from Shanxi to Beijing each year. In 2004 a 

3900km-long Western Gas (NO.1) pipeline was finished 

and its annual transmission capacity was 12 BCM. The 

second stage of Shanxi-Beijing pipeline was put into 

operation with its capacity 12 BCM in 2005 [2]. Western 

Gas (NO.2) pipeline construction was initiated in 2008 

and finished in 2012, and its capacity was 30 BCM. Natural 

gas from Burma began to supply China in July, 2013. 

It has been planned that natural gas from Russia can be 

delivered to China by 2018. Table 1 and Figure 1 summarized 

some distant pipelines in China. 

Liquefied natural gas (LNG) began to play an important 

role to satisfy rapidly-increasing demand in south- 

Table 1. Some long-distance pipeline projects in China 

Beginning Year Finish Year Origin location End location Length (km) Capacity 

(BCM/year) 

1 1992 1997 Shanxi Beijing 868 3.6 

2 2000 2004 Xinjiang Shanghai 3900 12 

3 2004 2005 Shanxi Beijing 918 12 

4 2007 2009 Sichuan Shanghai 2206 12 

5 

2008 2012 Kazakhstan Shanghai/ 

Guangdong 

4895 30 

6 2010 2013 Burma Yunnan/Guizhou 1727 12 

7 2013 2018 Russia 38 


Gas quality 

REPORTS 

eastern China. In 2006 the first LNG terminal in Dapeng 

(Guangdong) was put into operation, annual capacity 

being 3.7 million tons (MMT). From then on several terminals 

in Shanghai, Jiangsu, Dalian, Zhejiang were put 

into operation (as shown in Figure 1), and the total 

capacity increased to 24.2 MMT/a. It was expected that 

10 terminals would be constructed along Chinese 

coasts, and the total receiving capacity would climb up 

to 50.9 MMT/a by 2017 [3]. 

The supply pattern of natural gas in China can be 

summarized as “west-originated to east, north-originated 

to south, sea-originated to land”. Accompanied with 

gradual formation of long-distance pipelines and introduction 

of LNG, more and more areas will be or have 

been faced up with a fact that they are supplied with 

gases from different sources. For example, there are 5 gas 

sources in Shanghai and 6 gases in Guangdong. In Beijing, 

there are also 4 sources. 

The constituent differences of gases from different 

sources may introduce an uncertainty related to performance 

of appliances in end-users. There are as much as 

80 gas sources in China (including some potential 

sources), and their distribution in gas specification is illustrated 

in Figure 2 and Figure 3. The distribution of 80 

gas sources is so wide, and LNG is generally richer than 

pipeline natural gas (PNG) and offshore gas (OSG). CH 4 

vary from 72% to 100%, C 2H 6 and N 2 can account up to 

20%. In Chinese national standard GBT13611-2006 [4], it 

was prescribed that Wobbe index of natural gas must fall 

within 45.67 MJ/m 3 ~54.78 MJ/m 3 . But no specific limit 

with regard to constituent variation was strictly defined. 

Figure 1. Distribution of gas pipeline in China 

Figure 2. Properties of gas sources in China 

Figure 3. The various gas constituents of gas sources in China 


REPORTS 

Gas quality 

Therefore natural gas interchangeability problem arises in 

recent years. Both appliance manufacturers and local 

delivery companies show their concern with the problem 

if serious combustion-related difficulties may result and if 

it is necessary to strictly limit individual constituents. 

2. HISTORY OF GAS INTERCHANGE- 

ABILITY RESEARCH: A REVIEW 

Technically natural gas interchangeability can be treated 

as some kind of extension of gas interchangeability. A 

brief review of interchangeability research will be helpful 

as how to configure out theoretical and experimental 

approach, so as to answer following questions: will constituent 

difference of gases from different sources lead to 

difficulties of various burners? Can appliance manufacturers 

have enough capacity to deal with such differences? 

In 1915, a large-scale survey in US was performed, 

finally leading to four kinds of instability phenomena, viz. 

lift, flash-back, yellow-tip and incomplete combustion. 

On a diagram with primary-air and port intensity as coordinates, 

four curves represent these limits of instabilities. 

It was put forward the relationship between operation 

point of a specific appliance and four curves can determine 

a margin with which the appliance would operate 

stably. In 1926 an Italian engineer Wobbe established an 

index to evaluate influence of gas properties upon heat 

input rating of a burner. In 1927 American Gas Association 

(AGA) initiated a 6-year research project, finally leading to 

“C index” approach. Shortly soon it was suggested that 

flame speed should be included as an influencing factor 

in 1934. In 1941 Knoy derived a mathematical formula to 

predict interchangeability of liquefied petroleum gas 

(LPG). In 1946 AGA laboratory (AGAL) published “Research 

Bulletin 36” which put forward three indexes to quantitatively 

describe the degree of unstable phenomena 

related with atmospheric combustion. But incomplete 

combustion was not considered due to some technical 

reasons. The gas burners used by AGAL were made of 

cast-iron, with round-ports and ribbon-ports. In 1951 

Weaver published a 6-index method to predict interchangeability, 

after analyzing relationship between flame 

speed and experimental results of AGAL. Basically Weaver 

indexes represent the relative tendency of unstable combustion 

when interchanged. 

A research project presided by Delbourg (Gaz de 

France, GDF) was initiated in 1950 and a diagram-based 

method was established to predict interchangeability of 

manufactured gas, natural gas-air mixture, propane-air 

mixture, etc, in 1956. Combustion Potential (CP) was put 

forward to represent influence of inner cone height and 

its impact upon lift, flash-back and CO emission. On a 

diagram with corrected Wobbe index and CP as independent 

coordinate, Delbourg triangle defines an area 

within which a specific burner can operate satisfactorily. 

Two additional indexes were combined to judge if sooting 

and yellow-tip would be encountered. 

Another diagram-based method was put forward in 

1956 by Gilbert and Prigg to consider constituent 

changes resulting from manufactured gas process and 

raw materials. On G-P diagram flame speed was abscissa 

and Wobbe index was y-axis, both of which can be calculated 

directly from gas constituent. Four groups of 

gases, G4, G5, G6, and G7 were experimentally tested on 

typical burners to establish limits of various gases. In 

1964 Harris and Lovelace put forward a modified diagram 

to take into account introduction of natural gas 

into England and future potential of substitute natural 

gas (SNG). Later in 1978 their approach was refined by 

Dutton and allowable areas for long-term and shortterm 

operation were experimentally determined. Dutton 

method is still adopted to decide whether a gas can 

be introduced into networks in England. 

In 1980s Harsha, P. T. [5] pointed out that applicability 

of multi-index methods remained to be further clarified 

since most of these approaches were based upon experimental 

results from appliances popular at the time when 

experiments were carried out. In 1990s Liss, W.E. [6] suggested 

that interchangeability research should be 

emphasized again to evaluate the diversity of natural 

gases including LNG and coal-based natural gas. Ted A. 

Williams [7] systematically summarized interchangeability 

researches available and concluded that the main target 

of research should be transferred from natural 

gases—manufactured gas to constituent differences 

between natural gases from different sources, such as 

pipeline gas and LNG. 

In 2003 National Petroleum Committee (NPC) published 

a report “Balancing Natural Gas Policy-Fueling the 

Demands of a Growing Economy” to call for necessity to 

refresh interchangeability method so as to introduce nonconventional 

gas. In Europe EASEE-gas published EASEEgas 

CBP 2005-001/02 to put forward Common Business 

Practice in regard to gas specifications. Halchuk-Harrington 

et al [8] recommended that the concept of “interchangeability” 

should be extended to include ALL appliances, 

including gas-turbine, gas-engines. Furthermore it was 

pointed out that most researches available were based 

upon fuel gas rather than natural gas, targeting at establishing 

standards for peak-shaving plants and blending 

plants. In addition natural gas considered in previous 

research was apparently different from current gases, and 

only a small portion of gases had similar constituents with 

today’s natural gas and LNG. In 2009 Ennis C.J. et al [9] compared 

gas constituents and interchangeability methods in 

US with those in Europe. Test gases were compared to help 

understand interchangeability approaches and their applicability. 

It was concluded that it essential to re-evaluate 


Gas quality 

REPORTS 

present theories so as to justify what can be accepted 

when interchanged. In 2010 BP published “Gas interchangeability 

and quality control” to include some experiments 

incorporating pipeline gas and LNG. 

Previous research revealed that all the interchangeability 

results are based upon experiments according to 

realistic gas constituents and gas appliances. Both final 

judgment criteria as “Yes” or “No” and testing method 

vary from a country to another. Unfortunately, in this field 

no systematic research had been carried out and no reliable 

conclusion can be referred in China. On the other 

hand, the supply amount of natural gas and appliance 

increased dramatically in past decade. 

Some experiments were performed in Tongji University 

from 2011 to measure performance response of gas 

cookers and water heaters to different gases. Despite no 

well-established conclusion has been arrived, the work 

turned out to reflect present status of potential influence 

resulting from varying constituents. 

3. EXPERIMENT PROCEDURES 

3.1 Technical approaches 

Figure 4. The relationship between gas appliance test standard and 

performance 

Pressure regulator 

PNG 

Gas meter 

The gas interchangeability was literally defined as the 

ability of one gas to substitute another one on some 

appliances without materially changing the operation of 

appliances, including performance and emission, etc. For 

a specific appliance, the standards to which it is subjected 

always prescribe performance (including efficiency, emission, 

safety issues, etc.) in terms of minimum requirements. 

The testing procedures involved are also included. 

For example, a gas cooker must have efficiency higher 

than 50% (or 55%) and its CO emission (air-free) must be 

lower than 500ppm according to relevant Chinese standards. 

The performance data should be measured when 

fuelled by 2kPa of 12T-0 (Chinese classification number, 

equivalent to G20). For a “qualified” cooker which has 

efficiency 52% and CO 300ppm when fuelled by gas “A”, 

its efficiency drops to 48% while CO emission remains 

350ppm when fuelled by gas “B”. It is quite difficult to 

conclude if gas “B” can substitute gas “A”. In other words, 

both objective and subjective issues are involved in the 

field of interchangeability research. As shown in Figure 4, 

the detailed parameters used to describe performance 

also change from one kind of appliance to another. For 

atmospheric appliances in China, publicly accepted issues 

include lift, flash-back, yellow-tip, and CO emission but 

no consideration was taken to efficiency across the world. 

In this paper the sampled appliances were domestic 

cookers and water heater incorporating atmospheric 

combustion. Related standards include “GB 16410-2007 

Domestic gas stove” [10] and “GB6932-2001 Domestic gas 

instantaneous water heater” [11]. 

C 4H 10 

C 3H 8 

C 2H 6 

CH 4 

Figure 5. Gas blending system 

3.2 TEST RIG 

CO 2 

N 2 

3.2.1 Gas blending system 

The test gases were supplied by gas-blending system 

through which CH 4, C 2H 6, C 3H 10, C 4H 10 and N 2, CO 2, were 

blended to ensure exactly the same constituents as test 

gases. Also the same Wobbe indexes and CP were 

achieved. Gas-blending system including a 5m 3 storage 

tank was shown in Figure 5. The purities of individual 

components involved were as follows: CH 4 99.9%, C 2H 6 

99.5%, C 3H 10 99.95%, C 4H 10 99.95%, N 2 99.999%, CO 2 

99.6%. After all the individual components were fed into 

the storage tank, the mixture remained 3-5 hours while 

propeller was working. Then gas was sampled and analyzed 

by gas chromatography. When the constituents of 

blended gas fell within allowable limitations compared 

with test gases (listed in Table 2) [12], and the Wobbe 

indexes, heating values, of blended gases differed not 

much from those of test gases, the blended gas could be 

regarded as identical to test gases. 

Storage tank 

to Burners 


REPORTS 

Gas quality 

Table 2. Accuracy and reproducibility of gas chromatography 

Component range 

(mole %) 

Reproducibility (%) Accuracy (%) 

0~0.1 0.01 0.02 

0.1~1.0 0.04 0.07 

1.0~5.0 0.07 0.10 

5.0~10 0.08 0.12 

>10 0.20 0.30 

Gas storage tank 

aluminum pot 

thermometer 

U-shape pressure gauge 

stirrer 

thermometer 

gas meter 

gas cooker 

Figure 6. Illustration of gas cooker test rig 

gas stoarge tank 

gas meter 

water heater 

U-shape pressure gauge 

sample ring 

flue gas measurement 

flue gas measurement 

3.2.2 Test system 

According to Ref[10] and Ref[11], a gas cooker test system 

and a water heater test system, as shown in Figure 6 and 

Figure 7 respectively, were set up to measure heat input 

rating, thermal efficiency, flame shape and pollutant 

emissions. 

3.3 Test gas constituents and sampled gas 

appliances 

Three different types of natural gases, namely OSG, 

PNG and LNG, will be introduced into Guangdong 

networks successively from 2009 to 2020. Accordingly 

10 gases which have been presently available 

and are planned were selected as test gases in this 

paper. The detailed constituents of 10 test gases 

were listed in Table 3, among which PNG1 has the 

lowest Wobbe index and LNG5 has the highest 

Wobbe index, and PNG3, LNG2 similar to 12T-0 (G20) 

were in the middle of all gases. 

9 sets of gas cookers covering 9 different brands 

and three types of ports (namely, round, square, ribbon), 

and 6 sets of water heaters covering 3 different 

brands were selected as representatives of popular 

burner structures in Guangdong. The popular structure 

of gas cookers in China markets includes injector 

made of cast-iron, diffusion/distribution head made of 

aluminum or cast-iron, together with burner head 

made of casting copper alloys. Furthermore port intensity 

of Chinese gas cooker was usually designed to be 

7.0~9.0 W/mm 2 , much narrower than its US counterpart 

in 1950s (4.5~16.8W/mm 2 ) [5]. 

Figure 7. Illustrative schematic of water heater testing rig 

Table 3. Constituents and properties of natural gases for Guangdong test 

Mole% CH4 C2H6 C3H8 C4H10 CO2 N2 HV (MJ/m 3 ) WI (MJ/m 3 ) 

PNG1 96.00 0.70 0.20 0.10 2.30 0.70 37.04 48.3 

PNG2 92.79 4.00 0.30 0.30 1.80 0.80 38.39 49.4 

PNG3 98.90 0.20 0.22 0.20 0.00 0.46 37.70 50.7 

OSG1 85.99 9.61 0.20 0.00 3.60 0.60 39.10 48.8 

OSG2 84.40 4.70 2.40 5.20 0.90 2.40 43.84 52.4 

LNG1 98.50 0.00 0.30 0.10 0.00 1.10 37.63 50.1 

LNG2 97.00 1.90 0.30 0.10 0.00 0.70 38.30 50.6 

LNG3 90.70 7.50 0.30 0.10 0.20 1.20 39.68 51.1 

LNG4 89.40 6.00 3.20 1.10 0.00 0.30 42.12 52.9 

LNG5 86.60 9.00 2.90 0.90 0.10 0.50 42.53 53.0 


Gas quality 

REPORTS 

Figure 8. Measured performances of gas cookers when fuelled by different gases: 

(a) heat input rating, (b)thermal efficiency, (c) CO emission, (d) NOx emission 

4. RESULTS AND ANALYSIS 

4.1 Gas cooker 

4.1.1 Heat input rating 

Measured heat input rating of all sampled cookers under 

different gases was shown in Figure 8(a). It can be found 

that heat input rating increases almost linearly with the 

increasing Wobbe index for all cookers. This suggested 

the heat input rating of cookers change consistently with 

Wobbe index, and it also can be precisely predicted by 

Wobbe index; on the other hand, it also means that 

experiment results are quite accurate and reliable. 

4.1.2 Thermal efficiency 

Figure 8(b) shows the change of thermal efficiency 

with varying gas constituents. Obviously the change of 

thermal efficiency of gas cookers does not give any 

regular pattern. 

According to Ref [10], thermal efficiency of gas cooker 

must be measured by use of both upper-limit pot and 

lower-limit pot according to by heat input rating. Then the 

thermal efficiency is calculated by interpolation of heat 

intensity in terms of bottom area, viz. kJ/mm 2 . In fact such 

procedure considers the flame and heat transfer in a more 

objective way. However it tends to make the continuously 

changing issue discrete. Secondly, the specific process of 

combustion and heat transfer were greatly influenced by 

burner structure and those gas constituents which will 

seriously affect flame characteristics, such as flame luminosity, 

height and speed. That is the reason why in most 

published papers thermal efficiency was not taken as a 

quantitative index to evaluate interchangeability in China. 

It was prescribed in Ref [10] that thermal efficiency 

must not be lower than 55% (for on-top cooker) or 50% 

(for embedded cooker). From the experiment results it 

can be concluded that with the change of gas constituents, 

thermal efficiency of all samples are not very satisfactory. 

For all 9*10=90 operation points, only 75% (67 

operation points) can be considered as “qualified” in 


REPORTS 

Gas quality 

terms of efficiency, but there is no one gas cooker which 

can give “qualified” thermal efficiency under all tested 

gases. In other words, a lot of works remain to be finished 

for the manufacturers before a cooker with enough flexibility 

becomes available. 

Table 4. Test results of lifting for gas cookers 

C-A-1 

C-H-1 

PNG2 LNG1 LNG2 

PNG1 PNG2 OSG1 

PNG1 PNG2 PNG3 

4.1.3 CO emission 

From the very beginning of interchangeability CO emission 

has been a significant issue to characterize appliance performance. 

Usually there are clearly defined limits on CO emissions 

for safety reasons. Figure 8(c) 

illustrates CO emission of all samples 

under different gases. The change of 

CO emission with the gas constituent 

doesn’t follow any regular pattern. A 

slightly increasing trend of CO emission 

with increasing Wobbe index was 

observed, though the values of CO for 

most samples fell below 500ppm. In Ref 

[10] it is prescribed that CO emission (airfree) 

must not be higher than 500ppm. 

And it can be found that 6 samples 

can maintain lower CO emission 

under all tested gases, accounting for 

67%. For all 90 operation points, 78 

operation points (about 87%) can be 

considered as “qualified” in terms of 

CO emission. So it can be concluded 

that well-adjusted initial state of gas 

cookers can be flexible enough not to 

materially increasing CO emission. 

4.1.4 NOx emission 

C-D-1 

LNG1 LNG2 OSG1 

PNG1 PNG2 PNG3 

Figure 8(d) shows the NOx emission 

of samples under different gases. 

NOx emission of sampled cookers is 

found to increase with increasing 

Wobbe index, but NOx can be lower 

than 90ppm under most test gases. 

Anyway currently there is no mandatory 

requirement to specify the 

allowable NOx emission. 

4.1.5 Lift 

C-I-1 

LNG1 

OSG1 

For natural gas interchangeability 

research, lift has always been a focus 

issue due to the potential incomplete 

combustion or even explosion hazard. 

In Ref [10] lift is visually checked 

immediately 15s after ignition. The 

experiment results are shown in 

Table 4. It can be found that lift tends 

to happen to samples when fuelled 

by lean gas such as PNG1, PNG2, OSG1 

and LNG1. This can be attributed to 

the smaller flame speed resulting 

from higher inert contents. 


Gas quality 

REPORTS 

Figure 9. Measured performances of water heaters when fuelled by different gases: 

(a) heat input rating, (b)thermal efficiency, (c) CO emission, (d) NOx emission 

4.2 Water heater 

As illustrated in Figure 9(a) heat input rating of all sampled 

water heaters were found to increase linearly with 

Wobbe index increment. Compared with gas cookers, 

the increasing degree of input rating is somewhat different, 

though Wobbe index can also be used to predict 

changing trend of heat input rating. 

Thermal efficiency measurement results were 

shown in Figure 9(b), it can be found that variations of 

efficiency remain within 4~5 percentage points. It was 

specified that efficiency of third-/second-/first- class 

water heater should not be lower than 84%, 88% and 

96%, respectively. Two condensing water heaters 

(W-A-1 and W-C-2) gave efficiency higher than 96% 

and can be labeled as “qualified” under all 10 gases. 

Efficiency of W-C-1 dropped below 88% under PNG1 

and LNG1. The remaining 3 water heaters can give efficiency 

higher than 88%. 

As shown in Figure 9(c), only 5 measured points were 

observed to give CO emission above 600ppm (allowable 

highest concentration) which is specified by Ref [11]. All 

the other 4 water heaters can be termed as “qualified” 

under 10 gases, accounting for 67%. 

NOx emission did not give any regular pattern with 

change of gas constituents. Except for W-B-1 gave a 

90ppm+ under LNG4 and LNG5, all the other water heaters 

can keep an emission lower than 90ppm. An apparent 

trend can be found that NOx emission increase with 

increasing Wobbe index of gases. 

5. CONCLUSIONS 

Most interchangeability research available was performed 

by means of experiments on appliances popular 

at the time when the research was done. Because the 

structure, material, designing parameters of burners in 

current Chinese market differ much from those gas appliances 

almost 50 years ago, it is quite doubtful whether 

the well-established prediction methods (index- or diagram-based) 

can be applicable to present Chinese gases 

from different sources. 


REPORTS 

Gas quality 

9 gas cookers and 6 water heaters were experimentally 

tested and heat input rating, thermal efficiency, CO 

and NOx emission were measured when fuelled by 10 

gases which have been/will be supplied in Guangdong. 

The testing procedure and facilities involved strictly follow 

related national standards. The conclusions can be 

summarized as follows: 

(1) The performance of domestic appliances (including 

cookers and water heaters) are found to change with variable 

gas constituents. None of the 9 cookers can give satisfactory 

thermal efficiency under all 10 gases investigated. 

1/3 of cookers were found to emit higher concentration of 

CO and 44.4% of sampled cookers would have lift flame 

under low Wobbe index gases. Only 3 cookers can keep 

“qualified” in terms of both CO emission and lift, even if 

thermal efficiency was not taken as a necessary measurement 

index. 3 out of the 6 sampled water heaters can 

maintain second-class efficiency under all 10 gases while 

giving “qualified” CO emission. Half of sampled water heaters 

would degrade with changing gas constituents. 

(2) If a gas cooker was well-adjusted at the beginning 

of measurement, CO and NOx emission would not change 

materially. And most sampled appliances can tolerate the 

variation range of constituents. Gas cookers tended to 

decrease efficiency when gas constituents were changed, 

and more likely to become “unqualified”. For water heaters 

tested, thermal efficiency could be maintained within a 

range permitted by administrative requirement, and it 

seemed no serious problem would occur. 

The criterion as to decide whether a gas can be substituted 

by another one on a specific appliance depends on 

both the standard to which the appliance is subjected and 

the allowable margin, the latter of which is not fixed in terms 

of quantitative indexes around the world. The work in this 

paper can be considered as an initiating point to explore what 

would happen to domestic appliances if the gas constituents 

change to certain extent in China. Both theoretical analysis 

and experiments are needed to further reveal applicable 

index- or diagram-based method for Chinese gas industry. 

REFERENCES 

[1] BP Company. BP Statistical Review of World Energy 

June 2012 [2012-06]. 

[2] Nobuyuki Higashi. Natural Gas in China Market evolution 

and strategy [2009-06]. 

[3] Energy Information Administration. China Energy 

Data, Statistics and Analysis - Oil, Gas, Electricity, Coal 

[2010-11]. 

[4] General Administration of Quality Supervision, 

Inspection and Quarantine of the People's Republic 

of China (AQSIQ). GB/T 13611-2006 Classification and 

essential property of city gas. Beijing: China Standard 

Press, 2006. (in Chinese) 

[5] Harsha, P. T., Edelman, R. B., and France, D. H.: Catalogue 

of Existing Interchangeability Prediction Methods. 

Gas Research Institute, 1980. 

[6] Liss, W. E., Thrasher, W. H.: Variability of Natural Gas 

Composition In Select Major Metropolitan Areas Of 

The United States, Final Report, GRI-92/0123. Gas 

Research Institute, 1992. 

[7] Williams, T.A.: AGA Interchange Background: Technical 

issues and research need in gas interchangeability 

in the US [2006-06]. 

[8] Halchuk-Harrington, R. and Wilson, R.: AGA Bulletin 36 

and Weaver Interchangeability Methods: Yesterday’s 

Research and Today’s Challenges [2006-05]. 

[9] Ennis, C. J., Botros, K. K. and Engler, D.: On the Difference 

between US Example Supply Gases, European Limit 

Gases, and their Respective Interchangeability Indices 

[2009-05]. 



of China (AQSIQ).GB 16410-2007 Domestic gas stove. 

Beijing: China Standard Press. 2007. (in Chinese) 



of China (AQSIQ). GB 6932-2001 Domestic gas instantaneous 

water heater. Beijing: China Standard Press. 

2001. (in Chinese) 



of China (AQSIQ). GBT13610-2003 Gas composition 

analysis by gas chromatography. Beijing: China 

Standard Press. 2003. (in Chinese) 

AUTHORS 

Yangjun Zhang, Ph.D. candidate 

Gas Research Institute 

China | Tongji University 

Phone: +86 21 69583802 

E-mail: zyjtongji@163.com 

Prof. Dr. Eng. Chaokui Qin 

Gas Research Institute 

China | Tongji University 

Phone: +86 21 69583802 

E-mail: chkqin@tongji.edu.cn 


www.industrial-valves.de 

From Experts for Experts… 

The German journal “Industrial Valves” reports 

in English language on developments and 

solutions in valve technology for industrial 

applications. The prime emphasis of each issue 

is made up of up-to-date, practically orientated 

technical articles by highly capable authors. 

Other important features include company and 

product news. 

The journal provides highly topical information 

on valves and their components in the chemicals 

and processing industries, in power generating 

plant and thermal process applications, in the 

oil and gas field, in the water industry, wastewater 

management, in sterile applications and 

in industry in general. 

“Industrial Valves” also contains an extensive 

Buyer´s Guide for valves, actuators and access ories 

which is available at www.industrial-valves.de, 

too. 

Get your FREE ISSUE 

Download complete issues of Industial Valves 

www.industrial-valves.de 

Industrial Valves is published by Vulkan-Verlag GmbH, 45128 Essen, Germany 

For advertising, please contact: 

Helga Pelzer (Mrs.) 

Phone: +49 201 8200235 

h.pelzer@vulkan-verlag.de 

For Press informations, please contact: 

Wolfgang Mönning (Mr.) 

Phone: +49 201 8200225 

w.moenning@vulkan-verlag.de

REPORTS 

Gas quality 

Admissible hydrogen 

concentrations in 

natural gas systems 

by Klaus Altfeld and Dave Pinchbeck 

There are proposals to inject hydrogen (H 2) from renewable sources in the natural gas network. This measure 

would allow the very large transport and storage capacities of the existing infrastructure, particularly high-pressure 

pipelines, to be used for indirect electricity transport and storage. 

1. SUMMARY AND CONCLUSIONS 

The results of this study show that an admixture of up to 

10 % by volume of hydrogen to natural gas is possible in 

some parts of the natural gas system. However there are 

still some important areas where issues remain: 

■■ 

■■ 

■■ 

■■ 

■■ 

underground porous rock storage: hydrogen is a 

good substrate for sulphate-reducing and sulphurreducing 

bacteria. As a result, there are risks associated 

with: bacterial growth in underground gas storage 

facilities leading to the formation of H 2S; the consumption 

of H 2, and the plugging of reservoir rock. A 

limit value for the maximum acceptable hydrogen 

concentration in natural gas cannot be defined at the 

moment. (H 2-related aspects concerning wells have 

not been part of this project); 

steel tanks in natural gas vehicles: specification UN ECE 

R 110 stipulates a limit value for hydrogen of 2 vol%; 

gas turbines: most of the currently installed gas turbines 

were specified for a H 2 fraction in natural gas of 

1 vol% or even lower. 5 % may be attainable with 

minor modification or tuning measures. Some new or 

upgraded types will be able to cope with concentrations 

up to 15 vol%; 

gas engines: it is recommended to restrict the hydrogen 

concentration to 2 vol%. Higher concentrations 

up to 10 vol% may be possible for dedicated gas 

engines with sophisticated control systems if the 

methane number of the natural gas/hydrogen mixture 

is well above the specified minimum value; 

many process gas chromatographs will not be capable 

of analysing hydrogen. 

Investigations have been conducted to evaluate the 

impact of hydrogen as related to the above topics. At 

present it is not possible to specify a limiting hydrogen 

value which would generally be valid for all parts of the 

European gas infrastructure and, as a consequence, we 

strongly recommend a case by case analysis. Some practical 

recommendations are given at the end of the paper. 


In certain parts of Europe we have the situation already 

where the generation of 'renewable' electricity from 

wind and solar energy has led, from time to time, to production 

plants being shut down because the electricity 

generated exceeds local requirements and the transportation 

or storage capacities are inadequate. It's a problem 

that will become even more severe in the future because 

construction of new electricity lines and high-capacity 

pumped storage power plants is a costly and very lengthy 

process. Projects are therefore being discussed in which 

the surplus electricity is used to power electrolysers that 

will split water into its component parts, with the hydrogen 

being directly injected into natural gas pipelines for 

both storage and transportation. The concept has 

become known as "Power to Gas" or P2G. 

It is becoming more widely accepted that hydrogen 

could become an important energy carrier in the energy 

mix in the quest for sustainability, because it offers several 

benefits related particularly to the potential for energy 

storage. Indeed it's possible that, with the existing infrastructure, 

hydrogen/natural gas mixtures could be transported, 

stored and converted into electricity where 


Gas quality 

REPORTS 

required. However, if the addition of small quantities of 

hydrogen, up to 10 %, to natural gas pipelines is to be 

accepted, it must guarantee a technically feasible, economically 

viable and, crucially, safe system of storage, 

transportation and use. 

It's clear that the European natural gas pipeline network 

has the potential to offer such a solution and several studies, 

including the EC-supported NaturalHy [1] project, have 

examined the feasibility of using it as a means of widespread 

hydrogen storage and transportation. However a number of 

crucial aspects were not sufficiently addressed in earlier 

studies and work remains to examine these bottlenecks in 

the interaction between hydrogen and the wider European 

natural gas network, including aspects of utilisation. 

The volume of hydrogen that may be added to natural 

gas is limited. There are already some very low 'ad hoc' 

limits in place, but studies [1] have shown that, with certain 

restrictions, admixture up to 10 % is not critical in 

most cases. However, there are bottlenecks which this 

project sets out to identify, proposing, where possible, 

solutions so that the natural gas infrastructure can be 

developed sufficiently to support the storage and transport 

of hydrogen-natural gas mixtures in a move towards 

a low carbon economy. This will, of course, cause natural 

gas and electricity networks to become even more interdependent, 

as shown in Figure 1, and the project highlights 

the R&D that will be necessary to achieve a robust 

solution based on the existing natural gas grid and its 

various constituent components. 

The project was initiated by E.ON New Build and Technology 

GmbH, under the auspices of GERG, the European 

Gas Research Group, and has been conducted on behalf of 

a consortium of interested parties from a range of relevant 

industry sectors, including; gas industry; energy transmission, 

power generation, equipment manufacturers, institutes, 

etc. (See annex 1). Most of the work, which has consisted 

of reviews of existing work and literature searches, 

was carried out by a few, specially selected 'active' partners. 

No experimental work was involved but the collated, existing 

information has been substantially augmented by inhouse 

knowledge from both 'active' and project partners. 

3. COMBUSTION OF DIFFERENT GASES: 

GENERAL REMARKS 

The most important combustion parameters are Wobbe 

index, methane number and laminar flame speed. 

H-gases only are considered in this study. 

3.1 Wobbe index 

The Wobbe index (W) is an indicator of the interchangeability 

of different fuel gases. Regardless of calorific value, 

gases with the same W produce the same heat load in a 

Coalfluctuating 

fluctuating 

Figure 1. Convergence of power and gas infrastructures 

gas burner. Therefore W is by far the most important 

combustion parameter for gas appliances (except 

engines) and is specified in all countries. Admixture of 

hydrogen slightly decreases W (10 % hydrogen lowers W 

by some 3 %). Figure 2 illustrates the W of pure methane, 

biomethane (simplified analysis: C1=methane: 96 %; CO 2: 

4 %) and a "medium rich" LNG (C1: 92 %; C2: 5 %; C3: 2 %; 

C4: 1 %). (N.B.: % always means vol% in this paper). 

The W range is 13.8 kWh/m 3 -15.4 kWh/m 3 for the 

gases without hydrogen admixture and 13.5-15.0 kWh/m 3 

if 10 % hydrogen is admixed (Wobbe index reference 

temperatures: 0 °C (volume), 25 °C (combustion), 1.02325 

bar). It is obvious that the variations caused by the different 

gases are significantly higher than the effects caused 

by 10 % hydrogen. However, if biomethane is considered, 

local Wobbe specifications can prevent hydrogen injection 

because biomethane has already a low Wobbe index 

(H-gases only are considered in this study). 

- 

- 


REPORTS 

Gas quality 

4,9 

Wobbe index [kWh/m 3 ] 

20 

15 

10 

5 

14,5 

0 

14,9 14,5 

15,4 

15 

13,8 13,5 

15,4 

15 

13,8 13,5 

methane biomethane "medium rich" LNG 

without hydrogen 

Figure 3 shows the MN of the gases described in 

chapter 3.1 without/with 10 % hydrogen admixture. 

Again it can be concluded that the MN of different 

gases without H 2 show a greater variation (from 100 to 

e.g. 74) than the effect of 10 % hydrogen (reduction by ≤ 

10). However, if the natural gas already has a low MN 

(e.g. rich LNG) the admixture of 10 % hydrogen can 

result in an unacceptably low MN from a gas engine 

operator's perspective (combined heat and power 

plants, dedicated natural gas vehicles). 

Although the MN is an important parameter for 

gas engines it has not been specified in most of the 

EU member states. This may be changed as a result 

of the CEN TC 234 activities in developing a European 

gas quality standard which includes the methane 

number. 


gas with 10% 

hydrogen admixture 

3.3 Laminar flame speed 

110 

100 

90 

80 

60 

50 

40 

30 

20 

90 

10 

0 

100 

90 

103 


70 

100 

Figure 2. Wobbe index of different gases without / 

with 10% hydrogen admixture 

methane number 

103 

94 

74 

methane biomethane 70 "medium rich" LNG 

Figure 3. Methane number of different gases 

without / with 10% hydrogen admixture 

94 



74 

70 




Flame speed is a complex combustion parameter 

related to flash back and flame stability. Both laminar 

and turbulent flame speeds may be defined but, unfortunately, 

they are difficult to measure and are not, therefore, 

specified in technical rules and standards. 

Figure 4 illustrates that the experimental data for 

laminar flame speed, from different authors [3, 4, 5, 6, 7, 

8], have significant deviations but there is a trend to 

increasing flame speed with increasing hydrogen addition. 

There is typically a ~5 % increase of the laminar 

flame speed for hydrogen admixture of 10 %. This 

increasing trend is also true for different air ratios and 

combustion conditions. Relevant information, depending 

on the device, the addition of hydrogen to natural 

gas can also change the fuel-air ratio, which may 

change the flame speed significantly, as shown in Figure 

5 (Chapter 5.5). 

With regard to gas turbines, turbulent flame speed is 

an important parameter. However, relevant information is 

limited, but calculations [9] suggest that hydrogen has a 

stronger influence on turbulent flame speed. Hydrogen 

admixture of 10 % may result in a ~10 % increase in turbulent 

flame speed. 




4. NON-CRITICAL ASPECTS 

3.2 Methane number 

The methane number (MN) describes the knock behaviour 

of fuel gases in internal combustion engines and 

strongly depends on the specific gas composition and 

especially the amounts of higher hydrocarbons (C3, C4, 

C5) and hydrogen in the fuel gas. The MN of pure methane 

is 100, for pure hydrogen it's 0 and for rich LNG: 

65-70, according to the AVL method [2]. 


Various studies have shown that most parts of the natural 

gas system can cope well with hydrogen addition of 

up to 10 %, with no adverse effects and, as a result, they 

do not feature prominently in this paper. However, the 

whole system has been analysed and, for completeness, 

the components or particular aspects which should 

cause no problems are listed below: 

■■ 

natural gas transmission pipelines and compressors, 

despite concerns about hydrogen embrittlement; 


Gas quality 

REPORTS 

0,8 

0,8 

0,7 

0,7 

0,6 

0,6 

laminar flame speed [m/s] 

0,5 

0,5 

0,4 

0,4 

0,3 

0,3 

0,2 

0,2 

0,1 

0,1 

air ratio λ = 1 

air ratio pressure p = 1 atm 

pressure atm 

0 

0 5 10 15 20 25 30 

10 15 20 25 30 

Figure 4. Laminar flame speed 

versus hydrogen 

fraction in methane 

Hu 

Hu 

2009 

2009 

Cammarotta 

Cammarotta 

2009 

2009 

Miao 

Miao 

2008 

2008 

vol-% H 2 in CH 4 

vol-% 2 in CH 

Hermanns 4 

Hermanns 

2007 

2007 

Huang 

Huang 

2006 

2006 

Guenther 

Guenther 

1971 

1971 

GRI 3.0 

GRI 3.0 

■■ 

■■ 

■■ 

■■ 

■■ 

gas distribution pipework systems, including metering 

and billing equipment, seals, etc., where leakage 

was shown to be negligible; 

in-house pipework systems, with no problems 

reported at all; 

industrial applications, where no specific problems 

are anticipated if the Wobbe index of the gas mixture 

is well within the specified range. (See chapter 7); 

safety parameters (e.g. flammability limits, ignition 

energy, flame speed) affected only marginally; the 

increase of risk is very small. However special attention 

must be given to gas detection devices. (See chapter 

5.7). A re-assessment of the ATEX Zoning may be 

required, depending on the methods used; 

some standards recommend a maximum content of 

hydrogen and other components of 5 % (ISO 6976). 

More details are available in the full report 1 , although this 

is confidential to the project members. 

5. SENSITIVE COMPONENTS 

It's useful here to define what is meant by "sensitive components" 

and it's simply those elements of the gas system 

which are affected, or in the longer term, could 

deteriorate or could cause adverse effects in the presence 

of hydrogen admixtures up to 10 % in natural gas. 

As such, they are considered as limiting factors to the 

introduction of hydrogen into the natural gas system and 

require some investigation if they are to be understood 

and resolved. The specific effects vary depending on the 

component and may relate to the way processes operate, 

accuracy, susceptibility to corrosion effects, etc. As far as 

possible, all of the components known to be sensitive 

have been considered and are detailed below. 

5.1 Underground storage 

Gas storage is a key component in the natural gas chain 

and, in a future scenario, its various facilities could come 

into contact with natural gas/hydrogen mixtures. Little 

consideration has been given to this prospect until very 

recently, and experts have been reluctant to suggest a limit 

value for hydrogen addition because of the difficulty of 

identifying and quantifying the relevant processes among 

all possible reactions in underground storage facilities. 

There are three aspects to underground storage: inner 

reservoir phenomena, phenomena linked to the well and 

the phenomena of interactions between well and reservoir. 

This review focuses only on inner reservoir phenomena 

and excludes well phenomena and phenomena of 

interactions between well and reservoir. Wells, which link 

reservoirs to the surface, were excluded from the study 

but they are the subject of a parallel exercise 2 [10]. 

1 Copies are available to the general public from GERG at a cost of €500 

(€200 for universities) 

2 DGMK - Deutsche Wissenschaftliche Gesellschaft für Erdöl, Erdgas und 

Kohle e.V. 


REPORTS 

Gas quality 

Approximately twenty reservoir phenomena have 

been identified, all of which could impact reservoir 

exploitation. They have been ranked in importance, 

based on data found in the literature and from user 

experience, and, as a result, the review has been 

focused on four major types of storage or reservoirs, 

namely: aquifers, oil and gas depleted fields, salt caverns 

and lined rock caverns. 

The most serious issue, or potential issue, identified, 

particularly in aquifers and oil/gas depleted fields, is 

the potential for bacterial growth [11]. The associated 

issues are principally loss of gas volume and disappearance 

of injected hydrogen, whether partial or total. 

There is also potential for damage to the cavity itself, 

and production of H 2S. 

No problems were identified with salt cavern storage, 

so they could possibly be used for storage of 

hydrogen and natural gas mixtures, if necessary. However, 

it's important to note the potential for leaks from 

steel-lined rock caverns and we await results from the 

above-mentioned project. [10] 

It's clear then that the effect of bacteria is the main 

concern for underground storage of hydrogen and natural 

gas mixtures, specifically in aquifers and depleted 

fields, as the interaction phenomena are not well understood, 

nor is it easy to identify specific bacterial species 

and to know, or measure, their quantities in situ. 

In summary, it's not possible at the moment to 

define a limit value for the maximum acceptable 

hydrogen admixture for natural gas stored underground. 

Clearly more work is required on a number of 

aspects. (See chapter 6.1) 

5.2 CNG steel tanks, metallic and 

elastomer seals 

Addition of even small quantities of hydrogen to natural 

gas networks is currently a show-stopper with 

regard to steel CNG vehicle tanks. The potential for 

harmful interaction between hydrogen and steel has 

been known for many years and severe restrictions 

have long been in place. According to UNECE 3 Regulation 

110 for CNG vehicles, the H 2 content in CNG is 

limited to 2 vol %, if the tank cylinders are manufactured 

from steel with an ultimate tensile strength 

exceeding 950 MPa. This limit stems from the risk of 

hydrogen embrittlement which is known to cause 

accelerated crack propagation in steel and is, therefore, 

a critical safety issue. It's worth mentioning that 

the same 2 % limit is echoed in the corresponding ISO 

standard 11439 [12] and under DIN 51624, the German 

national standard for natural gas as a motor fuel. 

3 United Nations Economic Commission for Europe 

In Europe, quenched and tempered steel 34CrMo4 

is employed exclusively for CNG tanks and is compatible 

with hydrogen, provided that the tensile strength 

of the steel is less than 950 MPa, and that the inner 

surfaces of the cylinder have been inspected for allowable 

defects. However, existing steel CNG tanks are 

made predominantly of steel grades with a tensile 

strength greater than 950 MPa, because these materials 

allow smaller wall thicknesses and thus reduced 

weight of the cylinders, which is preferred for vehicle 

use. In addition, CNG tanks are not inspected for surface 

defects (simply since there is no need for it.) 

A key aspect here is that, under UNECE rules, car 

manufacturers are held responsible for the suitability of 

car components, including CNG tanks. This inevitably 

means that CNG vehicles will only be fuelled with natural 

gases containing more than 2 % hydrogen when 

substantial tests have proved that it's safe and the existing 

regulations have been amended accordingly. 

A complete screening of the existing tank population 

will be complex, as tests must prove that the storage 

tanks are safe under daily conditions, from -40 to 

+85 °C, including exposure to frequent cyclic loads 

induced by the fueling process and consumption and, 

finally, a lifetime of 20 years. So, clearly this will be a 

long-term process where, at the moment, final success 

cannot be guaranteed. 

In addition to the well-known embrittlement difficulties 

with hydrogen, there are concerns regarding leak 

tightness of seals, both metallic and polymer. All gas carrying 

components inside the vehicle are currently 

designed and tested for a maximum 2 % H 2. As a result, all 

such components are potentially critical and their ability 

to cope with higher H 2 fractions remains to be tested. 

5.3 Gas engines 

Despite the limited availability of published information 

in this area, the physics of combustion, supported by 

experimental evidence from real engines, shows that 

the increase in flame speed and reactivity caused by 

hydrogen addition to natural gas typically increases incylinder 

peak pressures. As described in chapter 3.2 the 

methane number decreases if the proportion of hydrogen 

(or higher hydrocarbons) is increased. 

This can result in: 

■■ 

increased combustion and end-gas temperature, 

which leads directly to enhanced sensitivity for engine 

knock and increased NOx emissions; 

■■ 

■■ 

improved engine efficiency, but with increased engine 

wear and increased (non-compliant) NOx emissions; 

reduced power output or tripping, for engines with 

knock control; 


Gas quality 

REPORTS 

■■ 

an adverse effect on lambda sensors which can 

cause an inaccurate (low) measurement of oxygen in 

the exhaust gas. (This will cause the control system 

to change the air: fuel ratio, resulting in a leaner mixture 

than intended, thus influencing performance 

and increasing both emission levels, especially NOx, 

and the possibility of misfiring). 

That even low fractions of hydrogen can precipitate 

engine knock, compared to the natural gas to which it 

has been added, directly implies one limitation on hydrogen 

fraction: if the knock resistance of the fuel is at the 

lowest value acceptable for an engine or population of 

engines and no adaption of engine operation is possible, 

then no hydrogen can be added to this gas. 

For natural gases with a relatively high knock resistance, 

such that the engines that use it have a substantial 

knock "reserve", the question of maximum hydrogen 

addition is complicated by other performance issues, 

partially related to the large diversity of engine types 

and field adjustments of the installed base. At the least, 

installed base engines are not expected to have controls 

to adapt engine conditions for (fluctuating fractions 

of) hydrogen addition. 

One of these performance issues regards NOx 

emissions; many gas engines that are not capable of 

adapting their operating conditions for hydrogen 

addition (air-fuel ratio, timing), and are at the permitting 

limit for NOx, can also admit no hydrogen. A 

more complex issue regards the consequences of the 

higher cylinder pressure for engine/component lifetime, 

reliability and maintenance requirements, which 

are more difficult to quantify. However, these issues 

are not hydrogen specific; for example, the admixture 

of LPG leads to similar effects. 

There are recommendations that 2 - 5 % hydrogen 

addition should be acceptable for engines, depending 

on the source of the gas. However, given the large and 

unknown variation in operating conditions of the 

installed base of engines, and the dependence of knock 

and NOx emissions on the gas composition supplied to 

any given engine, it is strongly recommended that a case 

by case approach be used to determine the maximum 

allowable hydrogen fraction. (See chapter 7). 

Most of the above has been derived from experience 

with stationary engines. Of course, the physical effects 

are the same for engines used in the transportation sector 

and, hence, the conclusions made here remain valid. 

5.4 Gas turbines 

It is widely understood that there are strict limitations to 

the degree to which hydrogen may be added to gas 

turbine fuel. It is normal for customers to specify a particular 

fuel, often depending on what is available locally, 

sometimes even process gas, so that the gas turbine 

combustion system could be carefully specified and 

tuned for optimum operation. 

Current fuel specifications for many gas turbines 

place a limit on hydrogen volume fraction in natural 

gas below 5 %. Exceptions are dedicated (syngas) gas 

turbines that can accept very high hydrogen fractions 

(> 50 %) and some specific gas turbines which are 

capable of burning natural gas containing 10 % hydrogen 

and even more. 

A large amount of literature exists on new gas turbine 

developments for gases containing high and 

mostly fixed fractions of hydrogen. However, literature 

relevant to hydrogen admixture in natural gas for the 

installed gas turbines is very rare. 

From an end-user point of view, Abbott et al [13] 

conclude that fuel composition variation can have an 

adverse impact on gas turbine operation, despite 

being within the range allowed in the grid and manufacturers’ 

specifications. The indication is, therefore, 

that for some gas turbines there is little or no margin 

for additional variations in fuel quality which reinforces 

the view that addition of even very low fractions of 

hydrogen to natural gas is likely to increase such issues 

for the installed gas turbine fleet. 

It seems clear that, for the installed base gas turbines, 

1 % must be considered as the general limit for 

hydrogen admixture to natural gas in a first step. Again, 

a case by case approach is required with special attention 

given to early or highly optimised DLN 4 burners. 

After tuning and/or modifications much of the installed 

base may be capable of tolerating 5 % to 10 % volume 

hydrogen admixture. 

Clearly, further work will be necessary to modify 

this situation. 

As with gas engines, admixture of hydrogen to natural 

gas fuels that are towards the extremes of current acceptability 

will prove more problematic than admixture to 

"mid-range" fuels. The development of criteria that limit 

the amount of hydrogen addition to extreme fuels while 

allowing more addition to mid-range fuels may aid the 

introduction of hydrogen to the natural gas network. 

5.5 Specific gas burners in the domestic sector 

The risk when mixing 10 % H 2 with natural gas 

depends on the combination of two factors: the primary 

air excess and the initial Wobbe index. Therefore, 

atmospheric burners used with low-Wobbe gas 

are more sensitive to H 2, if they have been adjusted 

with G20 (methane). 

4 Dry low NOx 


REPORTS 

Gas quality 

Table 1. Overall sensitivity from different sources 

by appliance type for 10% hydrogen in the 

natural gas 

Laminar flame velocity (m/s) 

0.5 

0.4 

0.3 

0.2 

0.1 

Addi5on of H2 

Effect on flame 

velocity 

Effect on air raDo 

Rich premixed 

combusDon 

Lean premixed 

combusDon 

Figure 5. Flame speed and air ratio for different gases 

77% CH4, 23% H2 (G222) 

80% CH4, 10% C2H6, 10% H2 

90% CH4, 10% H2 

100% CH4 (G20, methane) 

Addi5on of H2 

Effect on flame 

velocity 

Effect on air raDo 

0 

0.5 0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4 1.5 

Air ra5o ( ) 

BOILERS with 

full premix 

BOILERS without 

full premix 

COOKERS and OVEN 

WATER HEATERS 

SPACE HEATERS 

NEW TECHNOLOGIES 

PRE-GAD APPLIANCES 

1 for W > 48 MJ 

Theory 

CE 

approval 1 

Long term 

effects 

Testing 

No impact 

No impact but lack of tests 

Not known 

Impact 

The addition has a direct and indirect effect on the 

flame speed in burners used in domestic appliances: 

■■ 

it slightly increases the flame speed, as shown in Figure 

5 

■■ 

it increases the air ratio if rich premix burners are considered 

(unless there is a system that controls it) and 

so indirectly changes the flame speed. 

Figure 5 shows that, for rich premixed combustion, the 

addition of H 2 will result in both direct and indirect increase 

of the flame speed. For lean premix combustion, there will 

be an increase because of H 2 and an indirect decrease 

because of the air ratio. So a larger H 2 impact is expected 

with rich premixed combustion (atmospheric burners). 

All GAD 5 appliances (i.e. since the beginning of the 

90’s) have been routinely tested with test gas G222, 

which is a mixture of 23 % H 2/77 % CH 4, and this gives 

a strong indication that such a high H 2 content in natural 

gas is acceptable, at least in the short-term. There 

are however, some limitations to that conclusion 

amongst which are: 

■■ 

■■ 

the possible long term impacts, which are not known; 

the fact that some countries may have gases in 

which the Wobbe index can be lower than that of 

the G222 test gas. 

5 Gas Appliances Directive (Directive 2009/142/EC on appliances burning 

gaseous fuels) 

Table 1 summarises the current overall situation and it's 

clear that some uncertainties remain. (N.B. The results are 

valid for gas grids with a Wobbe number exceeding 14 

kWh/m 3 (equivalent to 48 MJ/m 3 at a reference temperature 

of 15 °C/15 °C), 1.01325 bar). 

On this basis, injection of 10 % of H 2 in natural gas grids 

(H gas) seems to be a reasonable future prospect for the 

domestic and commercial appliances considered. A "safety 

margin" should be taken into account. (See chapter 7). 

However, the uncertainties need to be clarified, and in 

that regard, it would be beneficial to initiate some additional 

tests to acquire more data, as detailed in 6.5. 

5.6 Gas chromatographs 

There is a problem with the current generation of process 

gas chromatographs (PGC) which use helium as the carrier 

gas and, as a result, are unable to detect hydrogen 

because of the relative proximity of their thermal conductivities 

(helium = 151 W/m*K; hydrogen = 180 W/m*K.). 

It's possible to solve this by retrofitting an additional 

separating column of argon as a carrier gas for hydrogen 

detection or by using new process gas chromatographs 

licensed for the metering of hydrogen. Another possibility 

might be to use PGCs with two single separating columns 

and two types of carrier gas. Some manufacturers 

have already developed new gas chromatographs ready 

for a hydrogen content up to 10 %. 


Gas quality 

REPORTS 

5.7 Leak detection 

Gas detection devices designed for natural gas may not 

be accurate for mixtures of natural gas and H 2. Some gas 

detection devices will be more sensitive for H 2 than for 

natural gas while others are not sensitive at all to H 2 and 

will only react to the fact that the methane is diluted. 

Semiconductor technology is suitable for detection 

of hydrogen/natural gas mixtures as it can identify 

methane as well as hydrogen. Most devices for measurement 

of the lower explosion limit of a gas mixture 

are configured for methane. Alarms are triggered upon 

reaching 10 % or 20 % of the lower explosion limit, i.e. 

0,44 % or 0,88 % methane in air. The lower explosion 

limit declines slightly (4,36 %) with admixture of 10 % 

hydrogen. Limitations to the functionality are therefore 

not expected. Manufacturers generally understand how 

the addition of H 2 to natural gas affects the accuracy of 

their equipment and devices can be adjusted and calibrated 

for use with hydrogen. 

FID devices (flame ionization detection - based on a 

hydrogen flame) and thermal conduction sensors have 

been designed for the specific detection of hydrocarbons, 

which means that these technologies can be 

applied only for low admixtures of hydrogen. 

The usual safety and screening methods with gas 

detector devices and detectors currently used for pipeline 

grid inspections (by foot, by vehicle, by helicopter) 

are typically FID or, in the case of helicopters, DIAL (differential, 

infrared laser, absorption spectroscopy); neither of 

these technologies is capable of detecting hydrogen but 

would be acceptable, in terms of accuracy, in situations 

with hydrogen admixtures up to 5 % in natural gas, as the 

main component of the gas remains methane. 

We must conclude therefore that the addition of H 2 

to natural gas changes the accuracy of gas detectors. 

Some will react on the safe side and others won't. It is 

essential, therefore, to re-calibrate gas detection devices 

when H 2 could be present in natural gas to ensure that 

they will react on the safe side. 

6. PROPOSALS FOR FURTHER 

RESEARCH 

6.1 Underground storage 

As bacteria are considered to cause the most severe 

problems, there have been attempts at eradication with 

disinfectants, but trials have been inconclusive to date, 

(froth/foam formation had caused problems). It is proposed 

now that more investigation is needed to overcome 

this problem. 

An alternative solution may be to separate the 

hydrogen from the natural gas before injection into 

storage and to store the hydrogen separately, and then 

to mix hydrogen and natural gas before injection in the 

gas network. (N.B. This separation of hydrogen from the 

natural gas/hydrogen mixture, using specially developed 

membranes, was investigated in some detail in 

the NaturalHy [1] project and was found to be both 

problematic and expensive.) 

There appears to be potential for estimating the 

impact of hydrogen addition following earlier attempts at 

numerical simulation by Maurer [14] and Bonnaud [15]. 

It may also be instructive to define a model for each 

kind of reservoir, to run simulations with various scenarios 

and to compare results with current projects such as 

HyUnder 6 or Underground Sun Storage 7 . 

6.2 CNG tanks, metallic and elastomer seals 

For the existing fleet of CNG vehicles, with steel tanks 

(type 1), the hydrogen limit for admixture with natural 

gas is set in accordance with ECE-R110 and DIN51624 

and CNG customers must be able to rely on the availability 

of compatible fuel. 

A dedicated research program, which may help to determine 

a higher limit for the existing fleet would be of limited 

suitability as it cannot replace the certification procedure 

covering the complete set of relevant specifications. So, a 

backdated fleet approval for higher hydrogen contents on 

the basis of a test program cannot be expected. 

Amendment of the existing regulations would imply 

that all CNG vehicle components in the field must be 

thoroughly investigated under all operation conditions, 

including all relevant parameters of durability such as 

hydrogen partial pressure, assembly temperature 

between -40 and +85 °C, relative humidity etc., in order to 

be approved for higher hydrogen contents. The enormity 

of this task suggests that it will probably never happen. 

It may be useful also to analyse the theory and 

assumptions that led to the current 2 % limit. 

In the future it may be possible to introduce CNG 

vehicles which are specifically designed to tolerate 

higher hydrogen content. As this is linked to higher 

expenditure, it will be implemented only when the 

introduction of higher hydrogen fractions in natural gas 

becomes a realistic prospect. 

If we assume increasing market penetration of such 

advanced CNG cars and the normal, progressive phase 

out of older models, a gradual transition to the acceptance 

of higher hydrogen levels in CNG would appear 

feasible. It is worth mentioning that this will be a longterm 

process as, for example, CNG vehicle tanks have a 

life-time guarantee of 20 years. 

6 www.hyunder.eu 

7 www.undergroundsunstorage.at (operational October 2013) 


REPORTS 

Gas quality 

6.3 Gas engines 

To allow higher fractions of hydrogen, engine configuration/adjustment/controls 

must be adapted to remove 

the physical cause of the issues: 

■■ 

■■ 

for engine knock, NOx and engine wear, the peak 

pressures and temperatures must be lowered to those 

that will negate the effects of hydrogen. However, it's 

clear that unless the hydrogen fraction, and the natural 

gas composition to which it is added, can be constant, 

adaptations will have to accommodate fluctuating 

amounts of hydrogen; 

modern controls for air-fuel ratio and/or ignition timing 

that make use of exhaust NOx sensors, temperature 

sensors or pressure sensors in the combustion 

chamber may compensate for fluctuating hydrogen 

fractions in the fuel. However, the adequacy of such 

solutions and the adaptability to the various engine 

types must be examined. 

So, to enable the fluctuating hydrogen content in natural 

gas to be increased, further work is required to resolve a 

number of issues: 

■■ 

■■ 

■■ 

effect of hydrogen on knock resistance and pre-ignition 

– a better method of accounting for the effects of 

hydrogen addition to the knock resistance of natural 

gas is required; 

the way in which engine control systems handle the 

effect of hydrogen on NOx emissions and combustion 

pressures must be examined. The installed base has a 

diversity of control systems with various components. 

Their response to, and the ways they handle, hydrogen 

admixture vary. Different engine types with different 

control hardware and software may require different 

adaptations; 

risk of occurrence of explosions in intake, crankcase 

and exhaust will increase with hydrogen admixture. 

The effects and measures that should be taken must 

be identified. 

6.4 Gas turbines 

Tests on gas turbines are required with specific attention 

being paid to starting, flame stability (pulsations and 

flashback) and emission issues. Two possible approaches 

are to build experience: 

■■ 

■■ 

with new turbines and expand conclusions to the 

installed base; 

from pilot hydrogen projects that inject hydrogen in 

the natural gas grid. 

For turbines and many other industrial processes it's important 

also to know the range and rate of change of the 

hydrogen content in natural gas. Consequently, this question 

has to be addressed before considering widespread 

injection of hydrogen in the gas network. (See chapter 7). 

The development of criteria that limit the amount of 

hydrogen addition to extreme fuels while allowing more 

addition to mid-range fuels may be beneficial. Consideration 

should be given as to whether common criteria may 

be applicable to gas turbines, gas engines and other 

combustion processes. 

6.5 Specific gas burners 

With regard to domestic applications, uncertainties 

remain which need to be clarified so it would be useful to 

acquire more data from additional series of tests on: 

■■ 

■■ 

■■ 

atmospheric burners, as the majority of the technologies 

on the market use these burners and the available 

test results do not sufficiently cover all segments 

of appliances; 

new technologies, especially those with features not 

previously present in the tests; 

pre-GAD appliances, for which we have don't have a 

documented safety margin, such as CE approval. 

Further investigations are recommended: 

■■ 

on potential long-term effects of hydrogen addition 

to natural gas, such as overheating of burners and 

heat exchangers; 

■■ 

to clarify the impact for Wobbe numbers below 14 

kWh/m 3 (under which CE approval results cannot 

be used). 

Finally, it is strongly recommended that, in EN 437, there 

should be a definition of new test gases and test procedures 

for approval of appliances that operate with hydrogen/natural 

gas mixtures; this would seem to be a fundamental 

requirement for preparing the future market. 

6.6 Leak detection 

Special attention must be given to gas detection devices 

because some are not sensitive to hydrogen. As a result, 

they see only the diluting effect of addition of H 2 to natural 

gas and will therefore give an inaccurate response. 

For measuring systems which are not able to detect 

hydrogen explicitly, such as FID and DIAL, modification or 

replacement is recommended for admixtures of hydrogen 

of more than 10 vol.%. This statement is a first recommendation 

and certainly needs further investigation. 

7. PRACTICAL RECOMMENDATIONS FOR 

HYDROGEN INJECTION 

In general, a case by case analysis is necessary before 

injecting hydrogen in the natural gas network. 


Gas quality 

REPORTS 

For the time being, porous rock underground gas 

storage is a "show stopper". 

Most gas chromatographs will require modification. 

It is recommended that manufacturers' specifications 

should always be followed, particularly when gas turbines 

or gas engines are connected to the network. 

However, on the basis that much of the natural gas system 

can tolerate admixture of up to 10 % by volume of hydrogen, 

depending on the specific local situation, the following maximum 

hydrogen concentrations are recommended: 

■■ 

■■ 

■■ 

2 % - if a CNG filling station is connected; 

5 % - if no filling station, no gas turbines and no gas 

engines with a hydrogen specification < 5 % are 

connected; 

10 % - if no filling station, no gas turbines and no gas 

engines with a hydrogen specification < 10 % are 

connected. 

N.B. For both 5 % and 10 %, care should be taken to 

ensure that the Wobbe index and methane number of 

the natural gas / hydrogen mixture are not close to the 

existing limit values for the network ("safety margins" for 

Wobbe index and methane number). 

Injection of hydrogen should be carefully controlled 

to avoid sudden increases of the hydrogen concentration 

in the natural gas (e.g. speed of change < 2 % / min). 

ACKNOWLEDGEMENTS 

The authors would like to thank GERG 8 and the project 

partners, as detailed in the annex, for their support 

and, in particular, the following active partners for 

their specific contributions: 

■■ 

■■ 

■■ 

■■ 

■■ 

■■ 

G. Müller-Syring, S. Schütz, DBI-GUT, (gas distribution 

systems, gas metering / billing) 

J. Schweitzer, M. Näslund, DGC, (domestic / commercial 

gas applications) 

A. Dijks, A. D. Bloemsma, H. de Vries, DNV Kema, (gas 

turbines / gas engines, analysis of safety relevant gas 

parameters) 

K. Altfeld, M. Hoppe, E.ON New Build & Technology 

GmbH, (CNG tanks / compressors, valves etc.) 

F. Lebovits, L. Nadau, R. Batisse, Nicolas Richard, GdF 

Suez, (transmission pipelines / underground storage / 

industrial applications) 

H. Rijpkema, W. H. Bouwman, Kiwa Technology, (inhouse 

installations) 

REFERENCES 

[1] Florisson, O. et al.: NaturalHy – Preparing for the hydrogen 

economy by using the existing natural gas sys- 

tem as a catalyst; An integrated project, Final Publishable 

Activity Report: http://www.naturalhy.net/ 

[2] Christoph, K.; Cartellieri, W. and Pfeifer, U.: Bewertung 

der Klopffestigkeit von Kraftgasen mittels der Methanzahl 

und deren praktische Anwendung bei Gasmotoren. 

MTZ 33, (1972), Nr. 10, pp. 389–429. 

[3] Cammarota, F.; Benedetto, A. D.; Sarli, V. D.; Salzano, E. 

and Russo, G.: Combined effects of initial pressure and 

turbulence on explosions of hydrogen-enriched 

methane/air mixtures. Journal of Loss Prevention in 

the Process Industries 22 (2009), Nr. 5, 607–613 

[4] Günther, R. and Janisch, G.: Meßwerte der Flammengeschwindigkeit 

von Gasen und Gasgemischen. 

Chemie Ingenieur Technik 43 (1971), Nr. 17, 975–978 

[5] Hermanns, R. T. E.: Laminar Burning Velocities of Methane-Hydrogen-Air 

Mixtures, Technische Universität 

Eindhoven, Diss., 2007 

[6] Hu, E.; Huang, Z.; He, J.; Jin, C. and Zheng, J.: Experimental 

and numerical study on laminar burning characteristics 

of premixed methane-hydrogen-air flames. International 

Journal of Hydrogen Energy 34 (2009), Nr. 11, 4876–4888 

[7] Huang, Z.; Zhang, Y.; Zeng, K.; Liu, B.; Wang, Q. and Jiang, 

D.: Measurements of laminar burning velocities for 

natural gas-hydrogen-air mixtures. Combustion and 

Flame 146 (2006), Nr. 1–2, 302–311 

[8] Miao, H.; Jiao, Q.; Huang, Z. and Jiang, D.: Effect of initial 

pressure on laminar combustion characteristics 

of hydrogen-enriched natural gas. International Journal 

of Hydrogen Energy 33 (2008), Nr. 14, 3876–3885 

[9] Brower M.; Petersen E.; Metcalfe W.; Curran H. J.; Füri M.; 

Bourque G.; Aluri N. and Güthe F.: Ignition delay time 

and laminar flame speed calculations for natural gas/ 

hydrogen blends at elevated pressures, ASME Paper 

GT2012-69310, Proceedings of ASME Turbo Expo 

2012, June 11-15, 2012, Copenhagen, Denmark 

[10] DGMK Research Report – Influence of hydrogen on 

underground gas storages, Project 752, expected 

end of year 2013 

[11] M. Wagner and Dr. H. Ballerstedt: Influence of Bio-methane 

and Hydrogen on the Microbiology of Underground 

Gas Storage / Einfluss von Biogas und Wasserstoff 

auf die Mikrobiologie in Untertagegasspeichern, 

Literature Study / Literaturstudie (DGMK-Project 756) / 

DGMK-Projekt 756, 2013, ISBN 978-3-941721-36-4 9 

[12] ISO Standard 11439: Gas cylinders - High pressure 

cylinders for the on-board storage of natural gas as a 

fuel for automotive vehicles 

[13] Abbott, D. J.; Bowers, J. P. and James, S. R.: The impact 

of natural gas composition variations on the operation 

of gas turbines for power generation, 6 th International 

Gas Turbine Conference, 17.-18. October 2012, 

Brussels, Belgium 

8 The European Gas Research Group (www.gerg.eu) 

9 Available from: www.dgmk.de/upstream/agber_untertagespeichert.html 


REPORTS 

Gas quality 

[14] Maurer, O.: Etude de la distribution des espèces soufrées 

et de la formation de l’hydrogène sulfuré dans 

les stockages de gaz naturel en aquifère, ENPC thesis, 

décembre 1992 

[15] Bonnaud, E.: Hétérogénéités compositionnelles 

dans les réservoirs de gaz acides. Compréhension et 

modélisation du rôle d’un aquifère actif, Ph.D. Thesis, 

École nationale supérieure des mines de Paris - 

Spécialité "Hydrologie et Hydrogéologie quantitatives", 

June 29 2012 

BIBLIOGRAPHY 

Recommended further reading: 

1. Power to Gas 

■■ 

■■ 

■■ 

G. Linke, K. Steiner, M. Hoppe, H. Mlaker, E.ON Ruhrgas, 

Power Storage in Smart Natural Gas Grids: Fiction or 

Fact? EGATEC, Copenhagen, May 2011 

K. Altfeld, P. Schley, E.ON Ruhrgas, Development of natural 

gas qualities in Europe, GWF international 2011 

Judd R., Pinchbeck D., Power to Gas Research Roadmap. 

Offering a solution to the energy storage problem? 

Gas for Energy, Issue 2/2013 

2. Underground storage 

■■ 

■■ 

■■ 

K. Schulze, Hydrogen and bacteria – the big unknown, 

4 th RWE Dea Research and Development Day, Hamburg 

16 th May 2013, Wietze Lab 

M. Pichler, Assessment of hydrogen-rock interactions 

during geological storage of CH 4-H 2 mixtures; Master 

thesis, Department Mineral Resources & Petroleum 

Engineering Chair of Reservoir Engineering, 2013 

J.-L. Garcia, Les bactéries méthanogénèses – The Methanogenic 

Archaea, C. R. Acad. Agric. Fr. 1998, 84, 23-33 

3. CNG tanks 

■■ 

■■ 

UN ECE Regulation No. 110: Uniform provisions concerning 

the approval of: 

■ Specific components of motor vehicles using 

compressed natural gas (CNG) in their propulsion 

system; 

■ Vehicles with regard to the installation of specific 

components of an approved type for the 

use of compressed natural gas (CNG) in their 

propulsion system. 

Barthélémy, H.: Compatibility of Metallic Materials with 

Hydrogen. Review of the Present Knowledge, International 

Conference on Hydrogen Safety, San Sebastián, 

Spain, Sept. 2007 

■■ 

EU-Project "Integrated Gas Powertrain", Final report, 

2012. http://www.ingas-eu.org 

4. Gas engines 

■■ 

■■ 

■■ 

K. Gillingham; Stanford University Department of Management 

Science & Engineering, Hydrogen Internal 

Combustion Engine Vehicles: A Prudent Intermediate 

Step or a Step in the Wrong Direction? 

S. Orhan Akansua; Z. Dulgerb, N. Kahramana, T. Nejat 

Vezirogluc; Internal combustion engines fuelled by 

natural gas-hydrogen mixtures; International Journal 

of Hydrogen Energy 29 (2004) 

Klell, M., Eichsleder, H. and Sartory, M., Mixtures of hydrogen 

and methane in the internal combustion engine 

– Synergies, potential and regulations, International 

Journal of Hydrogen Energy, 37(2012) 

■■ 

DIN 51624; Kraftstoffe für Kraftfahrzeuge – Erdgas – 

Anforderungen und Prüfverfahren Automotive 

fuels – Compressed natural gas – Requirements 

and test methods 

5. Gas turbines 

■■ 

■■ 

■■ 

M. Andersson, J. Larfeldt, A. Larsson, Co-firing with 

hydrogen in industrial gas turbines, SGC Rapport, 2013 

C. Marchmont, S. Florjancic, Alstom Baden, Switzerland, 

Alstom gas turbine technology trends, Proceedings of 

ASME Turbo Expo, 2012 GT2012 June 11-15, 2012, 

Copenhagen, Denmark 

S. J. Wu, P. Brown, I. Diakunchak, A. Gulati, Siemens 

Power Generation, Inc., Orlando, USA, M. Lenze, B. 

Koestlin, Siemens Power Generation Inc., Muelheim, 

Germany; Advanced gas turbine combustion system 

development for high hydrogen fuels, Proceedings of 

GT2007 ASME Turbo Expo 2007: Power for Land, Sea 

and Air; May 4-17, 2007, Montreal, Canada 

6. Gas burners 

■■ 

■■ 

■■ 

■■ 

■■ 

Nitschke-Kowsky, P., Wessing, W., E.ON Ruhrgas AG. 

Impact of hydrogen admixture on installed gas 

appliances. World Gas Conference (WGC), Kuala 

Lumpur, 2012 

EN 437 Test gases. Test pressures. Appliance categories 

Huang, Z., et al. Measurements of laminar burning 

velocities for natural gas-hydrogen-air mixtures, Combustion 

and Flame 146(2006) 

Di Sarli, V. and Di Benedetto, A., Laminar burning velocity 

of hydrogen-methane-air/ premixed flames, International 

Journal of Hydrogen Energy, 32 (2007) 

Ayoub, M. et al., An experimental study of mild flameless 

combustion of methane/hydrogen mixtures, 

International Journal of Hydrogen Energy, 37 (2012) 


Gas quality 

REPORTS 

■■ 

Levinsky, H. B., Consequences of "new" gases for the 

behaviour of gas utilization equipment, 2004, International 

Gas Research Conference, Vancouver 

7. Safety 

■■ 

■■ 

■■ 

De Vries, H., Florisson, O. and G. C. Tiekstra, Safe 

operation of natural gas appliances fuelled with 

hydrogen/natural gas mixtures (progress obtained 

in the NaturalHy-project), International Conference 

on Hydrogen Safety (ICHS 2007), San Sebastian, 

Spain, September 

Jurdik, E., Darmeveil, H. and Levinsky, H. B., Flashback 

in mixtures of molecular hydrogen and natural 

gas, 2004 International Gas Research Conference, 

Vancouver 

Lowesmith, B. J., Hankinson, G., Large scale high pressure 

jet fires involving natural gas and naturalgas/ 

hydrogen mixtures, Process Safety and Environmental 

Protection, Volume 90, Issue 2, March 2012 

AUTHORS 

Dr.-Ing. Klaus Altfeld 

Head of Gas Quality 

E.ON New Build & Technology GmbH 

Essen | Germany 

Phone: +49 201 184-8385 

E-mail: klaus.altfeld@eon.com 

Dave Pinchbeck 

Managing Director 

D Pinchbeck Consultancy Ltd. 

Melton Mowbray | England 

E-mail: davepinchbeck@hotmail.com 

(Former Secretary General, 

GERG Group, now retired) 

Annex 1. Partners 

Active partners 

DBI-GUT 

DGC 

DNV Kema Nederland BV 


GdF Suez 

Kiwa Technology 

Project partners 

Alliander N.V. 

BP Exploration Operating Company 

DBI-GUT 

DGC 

DNV Kema Nederland BV 

DVGW e.V. 

E.ON Gas Storage GmbH 

E.ON New Build & Technology Ltd 


Enagas S.A. 

Energinet 

Euromot 

EUTurbines 

Fluxys S.A. (ARGB) 

Gas Natural sdg 

Gassco AS 

Gasum Oy 

GdF Suez 

GL Noble Denton 

Infraserv GmbH & Co 

Italgas 

ITM Power GmbH 

Kiwa Technology 

National Grid plc 

Naturgas Energia Distribucion, Sau 

OGE GmbH 

ÖVGW 

RWE Dea AG 

Shell Global Solutions International B.V. 

Snam Rete Gas S.p.A. 

SVGW 

Volkswagen AG 

KOGAS - Korea Gas Corporation 

Germany 

Denmark 

The Netherlands 

Germany 

France 



U.K. 

Germany 

Denmark 


Germany 

Germany 

U.K. 

Germany 

Spain 

Denmark 

Belgium 

Belgium 

Belgium 

Spain 

Norway 

Finland 

France 

U.K. 

Germany 

Italy 

U.K. 


U.K. 

Spain 

Germany 

Austria 

Germany 


Italy 

Switzerland 

Germany 

South Korea 


REPORTS 

Gas storage 

Modern technical measurement 

concepts for the underground 

storage of natural gas 

by Achim Zajc and Michael Friedchen 

In the following contribution, the impact of restructuring and unbundling of the energy transportation companies 

based on the storage of natural gas in underground storages and here in particular the example of the EWE underground 

gas storage Jemgum from the point of view of measurement are considered. Starting from a conceptual 

overview, the detailed tasks of metering, such as accurate determination of the volume, determine the gas quality 

and the provision of process- as well as legal custody privacy and security. In summary, the authors give an outlook 

how they rated the future developments of measurement technology for underground gas storage. 


Large underground gas storage facilities are also generally 

referred to as natural gas storage. Around 50 natural 

gas storage facilities are in operation with an operational 

gas volume of approx. 20.5 billion m 3 . This puts 

Germany in 4 th place in international terms. Only 

Ukraine, Russia and the USA have larger volumes of 

operating gas [1]. 

Because of the increased dependency on imports 

and the very dynamic competition in the natural gas 

market, natural gas storage is gaining increasing importance 

in Germany and Europe. The decline in natural gas 

extraction in Western Europe and the ever-changing 

market conditions make natural gas storage both attractive 

and necessary. 

Demand for natural gas is by no means constant and 

varies significantly on the basis of daily and seasonal temperature 

variations and economic influences. To ensure 

that consumers can always rely on a secure, adequate 

and cost-efficient supply of natural gas, production and 

sales variations can be balanced using natural gas storage, 

among other things. [2] 

The rising dependency on imports and the very 

dynamic competition in the natural gas market mean 

that capacities have been increased drastically in recent 

years, as Figure 1 shows. 

The liberalisation of the gas market and the unbundling 

of energy supply companies, controlled by EU 

directives (2009/73/EC) explains why the classic function 

of natural gas storage facilities is changing. Thus, 

what used to be one of the central functions of energy 

supply companies, security of supply, is now becoming 

of secondary importance. A shocking report appeared 

at the beginning of April 2013: "Security of supply: GER- 

MANY'S NATURAL GAS STORAGE FACILITIES ARE 

ALMOST DEPLETED" [3]. 

It is thus all the more important to find extremely 

robust and reliable technical measurement solutions in 

terms of precision, data availability, data separation, security 

and management. This is precisely what the measurement 

concept of RMG by Honeywell aims to achieve. 

2. TECHNICAL MEASUREMENT 

CONCEPT FOR THE EWE 

UNDERGROUND GAS STORAGE 

FACILITY IN JEMGUM 

2.1 The EWE underground gas storage facility in 

Jemgum [4] 

EWE GASSPEICHER GmbH, which is located in Oldenburg, 

has a storage capacity of around 1.75 billion cubic meters 

of operating gas, making it one of the major storage 

operators in the German/European natural gas market. 

Storage capacity is divided between underground natural 

gas storage caverns in Nüttermoor and Huntorf in 

North-West Germany and in Rüdersdorf near Berlin. 


Gas storage 

REPORTS 

bn m 3 (Vn) 

22 

20 

18 

16 

Operating volume 

14 

12 

10 

8 

6 

4 

2 

0 

Former oil and gas deposits 

Aquifer 

Caverns 

Operation Planning 

Source: 

Operators, Yearbooks of Europäische Rohstoff- und 

Energiewirtschaft (VGE Verlag GmbH) 

Figure 1. Development of the operating volume of natural gas storage facilities [1] 

Another storage cavern is currently under construction 

in the region of Emden / Bunde / Oude Statenzijl at 

Jemgum. The first construction phase of the Jemgum 

storage facility will see EWE GASSPEICHER increase its 

overall capacity of around 1.75 billion cubic metres by a 

further 320 million cubic metres of operating volume. 

Since the first of April, four of the initial eight caverns in the 

first phase have been in the process of being filled with gas for 

the first time. The remaining four caverns will be filled after the 

end of the sol-phase in the coming year. The plan is that the 

first caverns should be ready for output in November 2013. 

Figure 2 [5] contains a schematic diagram of the 

natural gas storage. The measurement equipment is 

located in the area of the gas operating equipment 

(marked with a red circle). 

2.2 Overview of the technical measurement 

concept 

The natural gas storage facility is connected to three 

transport pipelines, while a fourth connection is available 

as a reserve for connecting another transport pipeline. 

Figure 3 shows the technical measurement solution 

from RMG by Honeywell. The gas operating equipment is 

designed for the following parameters: 

Figure 2. Schematic 

diagram of 

natural gas 

storage in 

Salzstock [5] 


REPORTS 

Gas storage 

Figure 3. Overview of the technical measurement concept 

■■ 

■■ 

■■ 

Operating pressure in the measured sections: 55-90 barg 

Intake capacity per measured section: 175,000 m 3 (Vn)/h 

Output capacity per measured section: 250,000 m 3 (Vn)/h 

data integrity of the individual line network operators. 

This demonstrates just how sensitive data security and 

management are in such projects. 

The various sections of the three measured section 

groups were implemented with a diameter of 250 mm 

(DN 250, ANSI 600). The fourth measured section group is 

intended for future expansion and is not used at present. 

In principle, the system solution can be divided into 

three parts: 

■■ 

■■ 

■■ 

Gas quality measurement 

Gas volume measurement 

Data management 

In the final analysis, the challenge lay in generating a 

measurement system that allows as many line network 

operators to be served as possible under weights and 

measures regulations. It was also necessary to ensure that 

all line network operators only have access to the data to 

which they are entitled. 

This is why all line network operators were kept separate 

in terms of measurement data, thus ensuring the 

2.2.1 Gas quality measurement 

Two type PGC 9000VC process gas chromatographs 

from RMG by Honeywell are used to determine the 

quality of the natural gas (Figure 4). Each of the process 

gas chromatographs is designed to analyse four process 

streams. In other words, the four process streams are 

analysed sequentially. Each analysis takes about three 

minutes. The chemical composition of the next process 

stream is then analysed, thus determining the calorific 

value of all four process streams. This means that the 

first process stream is analysed once again after a further 

9 minutes (three analyses). This yields four individual 

measurements per process stream and hour, which 

are used to form the mean value. 

Figure 3 underlines the redundant structure of natural 

gas quality measurement. Each process stream (one to 

four) is linked with process gas chromatograph 1. Each of 


Gas storage 

REPORTS 

Figure 4. 4-stream process gas chromatograph PGC 9000 VC from RMG by Honeywell 

these process streams is also linked with process gas 

chromatograph 2. In the event that one of the two process 

gas chromatographs fails or needs to be serviced, 

the chromatograph still in operation can be used to 

measure gas quality. This enables the greatest possible 

availability and flexibility to be achieved. 

The process gas chromatograph separates the natural 

gas into the following chemical components: 

■■ 

Nitrogen (N 2) 

■■ 

Carbon dioxide (CO 2) 

■■ 

Methane (CH 4) 

■■ 

Ethane (C 2H 6) 

■■ 

Propane (C 3H 8) 

■■ 

N-butane (n-C 4H 10) 

■■ 

Isobutane (i-C 4H 10) 

■■ 

Neopentane (neo-C 5H 12) 

■■ 

N-pentane (n-C 5H 12) 

■■ 

Isopentane (i-C 5H 12) 

■■ 

N-hexane (n-C 6H 14) 

Subsequent detection and identification of the percentage 

molar proportion enables the calorific value to be 

calculated according to ISO 6976 [6]. The process gas 

chromatographs are calibrated and subjected to intensive 

tests in the test centre run by RMG by Honeywell. 

The previously calibrated process gas chromatograph will 

be tested using genuine natural gas with a known chemical 

composition. The determined calorific value may not 

vary from the comparative sample by more than 0.1%. 

2.2.2 Gas volume measurement 

Gas volume measurement in the gas operating equipment 

involves three separate measurement section 

groups, each of which is assigned to a separate network 

connection. 

Each group consists of two parallel measurement sections, 

each with two MID-approved ultrasound gas 

meters connected in bidirectional series (Figure 4). A 

fourth measured section group is not implemented but is 

prepared for a future expansion of capacity. 

Figure 5 illustrates the bidirectional connection of 

two ultrasound gas meters in series with the three measurement 

section groups. Two different types of meter are 


REPORTS 

Gas storage 

used. The first is the USZ 08 ultrasound gas meter from 

RMG by Honeywell and second a Flowsic 600 ultrasound 

gas meter from Sick. The USZ 08 ultrasound gas meter 

uses tried-and-tested 6-path technology with all modern 

diagnostic functions [7]. 

Naturally, ultrasound gas meters are ideally suited to 

such an application. Firstly the loss of pressure is minimal 

and, secondly, unlike other meters such as turbine wheel 

gas meters, the meters can be operated in both directions 

with extremely high measurement performance 

and easy ducting (without diversion). In addition, for reasons 

of redundancy and increased availability in each 

measurement section group, two series circuits are operated 

in parallel. This means that if maintenance is required 

in one measurement section group, the relevant measurement 

section can be disconnected without impairing 

measurement or disrupting it in extreme cases. The ultrasound 

gas meters were calibrated on a high-pressure test 

bench prior to commissioning. During commissioning, 

the meters were once again tested under weights and 

measures regulations. 

Figure 5. USZ 08 ultrasound gas meter from RMG 

by Honeywell with a Flowsic 600 

ultrasound gas meter from Sick connected 

in series [8] 

Figure 6. Switching cabinets from RMG by 

Honeywell with MRG 2203 type 

measurement registration devices, DSfG 

and profibus gateways, Ethernet routers, 

and type ERZ 2104 flow computers and 

type GC9000 VC analysers, installed in the 

electrical equipment room of the gas 

operating equipment [9] 

2.2.3 Data management 

At present, communication involves six high-redundancy 

DSfG bus systems, a figure that will rise to eight in the 

final configuration level. This configuration will ensure the 

high availability the measurement data and render measurement 

data loss almost impossible. At the same time, 

all evaluation devices are connected via Ethernet and are 

visualised by means of an RMG by Honeywell evaluation 

unit. This dispenses with the need to use the individual 

devices when carrying out audits. Local auditing tasks are 

made much easier as a result. 

A profibus is used to connect to the higher management 

system. This ensures a high-redundant, calibratable 

measurement of gas volumes and quality and measurement 

data registration (MRG 2203 from RMG by Honeywell), 

as well as data communications for specific line 

network operators that can be selected in detail. ERZ 

2104 type flow computers from RMG by Honeywell were 

used for conversion purposes. 

All line network operators are kept separate in terms 

of measurement data, thus ensuring the data integrity of 

the individual line network operators. Data was separated 

through the use of communication units, such as the 

DSfG-DFY from RMG by Honeywell. 

Reliable measurement and analysis technology, as 

well as evaluation, registration and data transmission 

devices from RMG by Honeywell, enable high levels of 

redundancy, flexible communication, secure line network-specific 

data communications and convenient local 

auditing services. 

3. SUMMARY AND OUTLOOK 

In summary it may be said that the high degree of flexibility 

and integration capacity of the RMG by Honeywell 

products and the engineering performance enabled a 

very robust and highly efficient and reliable redundant 

system solution to be implemented for an extremely 

complex task under weights and measures regulations 

for the gas operating equipment used in the EWE natural 


Gas storage 

REPORTS 

gas storage facility in Jemgum. This system solution 

ensures a high level of data security and management 

among a large number of line network operators. 

Based on the example of this gas storage facility, it 

was possible to show that a forward-looking system solution 

can be achieved for the operation of a natural gas 

storage facility in particular under the changes in market 

requirements (liberalisation of the gas market). 

4. ACKNOWLEDGEMENTS 

The authors would like to thank EWE GASSPEICHER GmbH 

for supporting this publication. 

REFERENCES 

[1] "Untertage-Gasspeicherung in Deutschland" (Underground 

Gas Storage in Germany), ERDÖL ERDGAS 

KOHLE Volume 128, 2012, Issue 11 

[2] http://www.ewe-gasspeicher.de/erdgasspeicherung.php 

[3] http://www.handelsblatt.com/unternehmen/ 

industrie/versorgungssicherheit-deutschlandserdgasspeicher-sind-fast-leer/8029294 

[4] http://www.ewe-gasspeicher.de/speicher-jemgum-h.php 

[5] Approved graphic from EWE GASSPEICHER GmbH 

[6] EN ISO 6976, International Standard: @Natural gas -- 

Calculation of calorific values, density, relative density 

and Wobbe index from composition@, 2005 

[7] Zajc, A.: "Übersicht der Erdgasmessung mit Ultraschall 

unter besonderer Berücksichtigung der 

Online- oder "Live-Validierung" (Overview of natural 

gas measurement with ultrasound with special reference 

to online or "live" validation), gwf-Gas Erdgas, 

June 2012, 416 

[8] Approved photo from EWE GASSPEICHER GmbH 

[9] Approved photo from EWE GASSPEICHER GmbH 

AUTHORS 

Dr. Achim Zajc 

Product Marketing Manager 

Gas Metering 

Honeywell Process Solutions 

RMG Messtechnik GmbH 

Butzbach | Germany 

Phone: +49 6033 897 138 

E-mail: achim.zajc@honeywell.com 

Michael Friedchen 

Sr. Project Manager 

System Solutions 

Honeywell Process Solutions 

RMG Messtechnik GmbH 

Butzbach | Germany 

Phone: +49 6033 897 140 

E-mail: michael.friedchen@honeywell.com 

Import of Network Graph and Data (Text, 

CSV, XML, ODBC, ArcView, MapInfo, 

many GIS / CAD Systems), Import of 

Background Images (DXF, BMP, TIFF 

etc.), Show Maps and Elevation Data 

from Internet or Intranet Resources 

(WMS, OSM and others) 

STANET Network Simulation 

Gas, Water, District Heating, 

Steam, Waste Water, Electricity 

Stationary and Dynamic Simulation, 

Consumption Modeling based on Time, 

Temperature, Measurements and 

Consumption Billing, Events/Rules 

(PLC-Simulation), Mixtures of Qualities 

& Substances, Fire Flow Simulation, 

District Heating Simulation including 

Low Load and Condensation, Diameter 

Optimization, Height Interpolation, 

Routing and Capacity Analysis, Time 

Charts and Spatial Charts, Reports, 

Scenario Comparison 

Easy to use, Complete Help System, fast and scalable (more than 1 Mio Pipes) 

FISCHER-UHRIG ENGINEERING · BERLIN · GERMANY 

WWW.STAFU.DE 

INFO@STAFU.DE 

TEL.: +49 30 300 993 90 FAX: +49 30 308 24 212 

Please contact for a free evaluation version 


REPORTS 

Micro-CHP 

Seven things you need to know 

about Micro-CHP in Europe 

by Scott Dwyer 

In the past, Micro-CHP (5kWe and below) has been guilty of over-promising and under-delivering - not living up 

to the big opportunity many in the gas industry felt it offered. However, product choice in Europe has been 

steadily increasing over the last three years and some major global brands are now committing themselves to 

bringing micro-CHP product to market. The gas industry is showing some signs of the type of engagement 

needed to drive the European micro-CHP market towards success, but these examples are still limited to a 

handful of companies and countries. Gas industry involvement and support will be key if the technology is to 

achieve its full potential in a region containing 740 million people and 190 million buildings. New business 

models are also being proposed for capturing additional value from micro-CHP – leading to increasing interest 

in what ultimately remains an industry defined by much uncertainty. For those wanting to consider where the 

value could be for them, here are seven things you should know about Micro-CHP in Europe. 

1. GERMANY IS EUROPE’S LEADING 

MARKET 

With fifteen micro-CHP systems to choose from, the 

market has moved on from 2009 when there were only 

a few products available for larger homes or small 

businesses. However, of these fifteen, eleven are only 

available to customers in Germany. This is due to several 

reasons: higher electricity prices in Germany 

making self-generation of power more attractive, 

supportive policy, and a greater willingness of 

customers to innovate with their heating systems. In 

the short-term, Germany will continue to be the 

dominant market in Europe for micro-CHP, remaining 

Manufacturer 

BDR Thermea 

Kirsch Energy Systems 

Product name 

Technology 

Capacity 

(kWe) 

First 

commercialised 

Senertec Dachs ICE 5.5 Germany, 1997 

Ecogen / eVita SE 1 UK, 2010 

Senertec Stirling SE SE 1 Germany, 2011 

L4.12 ICE 4 Germany, 2011 

Nano ICE 1.8 Germany, 2013 

Lion Energy Powerblock SE 1.5 Germany, 2011 

Proenvis 

Primus 1.4 ICE 4 Germany, 2011 

Primus 5.2 ICE 1.9 Germany, 2013 

RMB Neotower ICE 5 Germany, 2011 

Vaillant 

Ecopower 3.0 ICE 3 Germany, 2009 

Ecopower 4.7 ICE 4.7 Germany, 2005 

Vaillant / Honda Ecopower 1.0 ICE 1 Germany, 2010 

Viessmann 

Vitotwin SE 1 Germany, 2011 

Vitobloc EM-5/12 ICE 5 Germany, 2012 

Yanmar CP5 ICE 5 Japan, 2002 

Table 1. Micro-CHP 

products available 

in Europe 

in 2013 

Source: Delta-EE, 2013 

Key: ICE = internal combustion 

engine, SE =Stirling Engine 


Micro-CHP 

REPORTS 

Figure 1. European micro-CHP market share by 

manufacturer (2005-2012) 


Note: * = no longer trading 

Figure 2. Global micro-CHP sales by country 

(2005-2012) 


the launch market of choice for many companies looking 

to introduce their products. 

More product is expected to arrive from 2014 

onwards – again, mainly in Germany. However, we 

should see launches extending into new markets as 

well, which will be crucial if manufacturers are to 

increase volumes and thus help bring prices down. 

2. EUROPE’S MARKET LEADERS 

ARE ITS #2 AND #3 BOILER 

MANUFACTURERS – BUT THEY STILL 

LAG BEHIND THE GLOBAL LEADER, 

JAPAN’S HONDA 

BDR Thermea is Europe’s market leader in micro-CHP, 

having sold almost 30,000 systems to date. As one of 

the "Big 5" European heating equipment manufacturers 

(number 3 in Europe with an annual turnover of around 

€ 1.8 billion), its portfolio features several micro-CHP 

products utilising various technologies. This includes 

5.5 kWe internal combustion engine (ICE) (under the 

"SenerTec" brand), 1kWe Stirling engine products (available 

under "Baxi", "Brötje", "Remeha", and "SenerTec" 

brands), and also 1kWe fuel cell product (under the "Baxi 

Innotech" brand) that’s still pre-commercial but due to 

launch in Germany from 2014. 

Vaillant – another of the "Big 5" and number 2 in 

Europe with total annual turnover of around € 2.3 billion 

– also has a variety of micro-CHP products in its portfolio. 

These include three ICE products of varying outputs: a 

1kWe system (sold in partnership with Honda) as well as 

larger 3 kWe and 4.7 kWe systems. Vaillant are also developing 

1 kWe Stirling engine and fuel cell products. The 

remaining players in the "Big 5" – Viessmann, Bosch, and 

Ariston – are also all involved in either selling or developing 

micro-CHP products. Nevertheless, they are all still far 

behind Honda of Japan which still dominate the global 

market, having sold more than 120,000 of its 1 kWe ICE 

micro-CHP since its home market launch in 2002. 

3. THE SIZE OF THE OPPORTUNITY IS 

AN ANNUAL HEATING MARKET OF 

8 MILLION GAS BOILERS – WORTH 

AROUND €25 BILLION EACH YEAR 

Those companies involved in gas-fired micro-CHP see it 

as the natural successor to the conventional - and hugely 

popular - gas boiler. Across Europe, around 8 million boilers 

are sold each year, with the market value estimated at 

around € 25 billion. While micro-CHP won’t be a perfect 

replacement for each of those boilers, taking just 4 % of 

the market would make it a billion euro industry. The 

small commercial and multi-family home markets offer 

micro-CHP vendors further potential for sales (Germany 

alone has almost 3.5 million multi-family homes). 

4. JAPAN IS THE GLOBAL LEADER IN 

MICRO-CHP AND ITS COMPANIES 

HAVE THEIR SIGHTS SET ON EUROPE 

Japanese sales of micro-CHP now outnumber those in 

Europe by around 10 to 1. This has been achieved through 

concerted support from Government, encompassing 

both R&D and a staged market introduction phase. 

Another reason for Japan’s leading position is the fact 

that the manufacturers and the gas industry have joined 

forces, helping to find synergies in the supply chains and 

creating a single, recognisable "brand" for micro-CHP. This 


REPORTS 

Micro-CHP 

50.000 

ICE ORC PEMFC SE SOFC 

5. SOME IN THE GAS INDUSTRY ARE 

PIONEERING NEW WAYS OF HELPING 

THE PRODUCT TO MARKET 

0 

2005 2006 2007 2008 2009 2010 2011 2012 

Figure 3. Global micro-CHP sales by technology 

(2005-2012) 


Key: ICE = internal combustion engine, SE =Stirling Engine, ORC = 

organic Rankine cycle, PEMFC = proton exchange membrane fuel 

cell, SOFC = solid oxide fuel cell. 

collaboration has been helped by the vertical integration 

of the gas industry and the recent energy policy move 

away from nuclear. 

Japan is now targeting Europe with its micro-CHP 

products and know-how – seen as a way of reducing the 

cost of the technology in its domestic market, as well as 

driving growth in the country’s export economy. 

There are a number of reasons why companies from the 

gas industry are actively engaged in trying to help micro- 

CHP succeed. One common reason is to secure the share 

of gas in the residential heating market while still meeting 

the obligations set by the gradual policy push towards 

more energy efficient, low-carbon options. Another 

strong motivator for gas industry involvement in micro- 

CHP is the realisation that it can help with customer retention 

and provide additional value beyond units of gas and 

electricity, such as with balancing supply and demand. 

European gas industry involvement in micro-CHP so 

far has spanned the entire value chain: from providing 

small financial incentives (such as provided by Wingas 

and E.ON) and assisting in product development (as EWE 

has done with fuel cell developer CFCL), to supporting 

laboratory and field tests (GDF Suez’s approach) as well as 

selling and installing product (like British Gas). 

New micro-CHP business models are also being tried 

and tested by current market players and innovative new 

entrants. With high prices and weak returns, a lack of 

product, and route-to-market challenges so far limiting 

the customer base, novel ways of selling are being sought 

as a means to bypass these barriers. 

100 

90 

Rankine cycle 

S-rling Engines 

Thermal Efficiency, LHV (%) 

80 

70 

60 

50 

40 

30 

Stirling engine 

Pico-‐turbine 

Internal combustion engine 

PEM fuel cell 

SO fuel cell 

Internal combus-on engines 

Rankine-‐cycle engines 

PEM Fuel Cells 

Pico-‐turbines 

20 

Solid Oxide Fuel Cell 

10 

0 

0 20 40 60 80 100 

Electrical Efficiency, LHV (%) 

Reference showing 85% 

overall efficiency 

Figure 4. Micro-CHP product efficiencies grouped by technology 




Micro-CHP REPORTS 

Order now! 

6. THERE IS AN INCREASING RANGE OF 

TECHNOLOGIES TO CHOOSE FROM 

BUT ICE STILL DOMINATES IN EUROPE 

There are generally five types of micro-CHP technology. 

All are at various stages of commercialisation in Europe 

but ICE – the most mature of them all – remains the bestselling 

one. Despite its maturity, ICE does have several 

drawbacks for residential applications which have led to 

the pursuit of other technologies (such as Stirling engine, 

Rankine cycle, pico-turbines, and fuel cells). Each has its 

own strengths and weaknesses and, crucially, each is 

suited to certain building types with particular energy 

demands. This means that provided there is a gas connection, 

there is an increasing chance that there will be a 

micro-CHP product suited for your building. 

7. IT'S A MARKET OFFERING GREAT 

POTENTIAL YET CHARACTERISED 

BY HUGE UNCERTAINTY 

Although the market today remains limited with huge 

uncertainty shrouding just how much growth potential 

exists, a number of major corporations remain committed 

to micro-CHP. These include many of Europe’s major 

energy utilities (E.ON, RWE, British Gas, GDF Suez, SSE), 

some of its biggest heating equipment manufacturers 

(BDR Thermea, Bosch, Vaillant, Viessmann, Ariston), as well 

as some high-profile global brands from Japan (Aisin- 

Seiki - part of the Toyota group, JX, Panasonic, and 

Toshiba). With the combined resources of all these organisations, 

it seems implausible to think that they won’t be 

able to kick-start the fledgling micro-CHP market in 

Europe. To unlock micro-CHP’s potential, they will need a 

stable policy environment, ensure their products reach 

the market on time and at a reasonable cost, and foster 

greater involvement from the wider energy industry. 

The gas industry is already active in the type of 

engagement needed to drive the micro-CHP market – 

but such examples remain isolated. Continued and intensified 

gas industry involvement and support will be 

needed if the future growth potential of micro-CHP in 

Europe is to be realised. 

AUTHOR 

Dr. Scott Dwyer 

Delta Energy & Environment Ltd. 

Edinburgh | United Kingdom 

Phone: +44 131 625 3213 

E-mail: scott.dwyer@delta-ee.com 

gas for energy is published by DIV Deutscher Industrieverlag GmbH, Arnulfstr. 124, 80636 München, Germany 

A close up view of 

the international 

gas business 

This magazine for smart gas technologies, infrastructure and 

utilisation features technical reports on the European natural 

gas industry as well as results of research programmes and innovative 

technologies. Find out more about markets, enterprises, 

associations and products of device manufacturers. 

Each edition is completed by interviews with major company 

leaders and interesting portraits of key players in the European 

business. 

READ MORE ABOUT 

Gas applications Grid infrastructure Measurement 

Gas quality issues Pipeline construction Regulation 

Biogas injection Corrosion protection Smart metering 


FUTURE 


REPORTS 

Biogas 

Ensuring operational safety of 

the natural gas grid by removal 

of oxygen from biogas via 

catalytic oxidation of methane 

by Felix Ortloff, Frank Graf and Thomas Kolb 

In Europe, in particular in Germany, biogas features a strong growth. The overall biogas capacity in Germany is 

to be increased to a level which will afford a recompression of biogas from local gas distribution networks or 

direct injection of biogas into the high pressure transportation network in future. Due to the fact that biogas 

typically contains certain amounts of oxygen, german authorities have set up a threshold value of 10 ppmv, 

following EASEE-gas recommendations, in order to protect the gas infrastructure and gas storages from 

corrosion. Since a small amount of oxygen is inevitable, some promising new options for the removal of oxygen 

have been identified within a recent DVGW survey. One promising alternative to state of the art technologies is 

the catalytic oxidation of methane. Currently detailed investigations are being performed in a catalytic test rig at 

the Engler-Bunte-Institute, in order to gain some basic design data for the implementation of a catalytic oxygen 

removal unit based on the utilization of biomethane in a technical scale. 


The production and injection of biogas into the natural gas 

grid is politically promoted in Germany [1]. Also in other 

european countries, some efforts are currently being undertaken 

to increase the overall biogas capacity. For Germany, 

the Gas Grid Access Regulation Act (GasNZV) sets up ambitious 

goals by defining the annual amount of injected 

biogas to be about 6 billion m 3 STP by the year 2020 (in 

2030: 6 billion m 3 STP) [2]. In the last years about 130 injection 

plants have been installed in Germany with a total 

annual injection rate of about 0.7 billion m 3 STP. If the political 

goals will be achieved, an increasing amount of biogas 

has to be recompressed from the local gas distribution grids 

into the national gas transportation network due to capacity 

limitations, especially in the summer season (Figure 1). 

In recent DVGW biogas monitoring programs oxygen 

contents in the injected biogas ranging from lower than 

0.1 vol.-% up to 1.8 vol.-% have been reported [3]. Thus, a 

higher concentration of oxygen has to be expected in 

the transportation network in future, where the total 

amount is limited to 10 ppmv for transport pipelines connected 

to underground storages and/or cross border 

transmission by federal law, following EASEE-gas recommendations 

[4, 5]. By exceeding this threshold, corrosion 

in gas installations may occur. Even worse, storage infrastructure 

(particularly pore storages) may be damaged by 

deposition of oxidized minerals as well as elemental sulfur, 

caused by the oxidation of hydrogen sulfide [6, 7]. 

Therefore, critical points of oxygen intake during the 

biogas production and purification process were identified 

within a DVGW research project [8]. Recommendations on 

the optimization of the biogas upgrading chain against 

the background of preventing oxygen intake were given. 

Since a small remaining amount is inevitable, options for 

the removal of the oxygen from biogas were presented. 

Up to now, oxygen is usually removed by adsorption 

based processes (e. g. on Cu, Cr) or by catalytic oxidation 

of hydrogen. The amount of oxygen in biogas typically 

exceeds the threshold value for economical application 

of adsorption based processes [8]. One promising alternative 

is the catalytic oxidation of methane. The most 

important advantage of the utilization of methane 

instead of hydrogen as a fuel for the oxidation reaction 



REPORTS 

Figure 1. Overview over a typical biogas 

plant setup, points of oxygen 

intake and spreading of the oxygen 

load in the gas grid infrastructure 

( : possible installation points for 

O2-removal units) 

is that methane is available in situ, whereas hydrogen 

has to be supplied, stored and added separately. 

Besides, the utilization of methane appears to be the 

more sustainable as well as the economically and technically 

preferred option [8]. 

Hence, experimental investigations on the removal 

of oxygen are currently being performed at Engler- 

Bunte-Institute in lab scale [9]. The examinations focus 

on the selection of suitable and economically feasible 

catalyst materials and on determination of required 

reaction conditions for compliance with the limiting 

value of 10 ppmv oxygen in the gas grid and therefore 

consequently also in the biogas. 

2. SOURCES FOR OXYGEN INTAKE 

It is common, that several process steps in the biogas 

purification chain can cause oxygen intake into the 

biogas. Besides oxygen intake during the feeding of 

biomass into the fermenter and the desulfurization 

process (especially when carried out by injecting 

ambient or oxygen enriched air directly into the gas 

phase of the fermenter), physical scrubbing processes 

act as main sources for oxygen [8]. Figure 1 illustrates 

a typical configuration of a biogas plant with a physical 

scrubber for CO 2-removal. Common points of oxygen 

intake are indicated. 

The design of the biomass feeding system depends 

on the nature of the substrate. In case of predominantly 

solid substrates, solid dosing systems, e. g. screw conveyors 

are applied. Such systems are not completely gas 

tight. Despite the substrate is compressed in the conveyor, 

it still exhibits certain porosity. As a result a small 

amount of ambient air is fed into the fermenter. Oxygen 

contents in a range of 0.1 vol.-% up to 0.4 vol.-% were 

calculated by taking into account the apparent density 

and the void fraction of typical solid substrates [8]. Nevertheless, 

nearly all of the oxygen is consumed by the 

reduction reaction of hydrogen sulfide to elemental sulfur 

directly in the fermenter: 

2 H 2S (g) + O 2(g) → 2 S (s) + 2 H 2O (g) (1) 

Hence typical oxygen contents are low (about 0.1 vol. %) 

downstream of the fermentation process. When liquid 

substrates are applied oxygen intake by the feeding system 

can be neglected [8]. 

In some cases, the desulfurization process is carried 

out by supplemental injection of ambient or oxygen 

enriched air directly into the gas phase of the fermenter. 

Thus the remaining amount of H 2S can be reduced to 

about 50 - 100 ppmv following eq. 1. However, oxygen 

has to be fed in slight excess to the stoichiometric necessary 

amount, resulting in relatively high oxygen contents 


REPORTS 


biomethane (+ H 2 O (g) ) 

Q . WT-01 

WT-03 

Q . 

K-01 

K-03 

K-02 

WT-02 

„lean gas“ 

CO 2 + H 2 S + H 2 O (g) 

+ Luft (+CH 4 ) 

raw biogas 

V-01 V-02 

D-03 

V-03 

air 

D-01 D-02 

P-01 

condensate 

K-01: Absorption 

column 

K-02: Flash 

K-03: Desorption 

column 

Figure 2. Common configuration of a physical absorption process for biogas upgrading (in this case the 

Genosorb ® 1753 solvent is applied) 

in the raw biogas (0.2 to 0.4 vol.-%). In respect of preventing 

oxygen contamination, alternative processes for desulfurization, 

such as desulfurization with ferric salts (FeCl), 

should be preferred. 

Not least, physical scrubbing processes cause a 

distinct increase of the oxygen content. When 

applied for biogas upgrading, such processes usually 

exhibit a configuration as shown in Figure 2. The raw 

Figure 3. Residual contents of oxygen in biogas, 

measured in a recent biogas monitoring 

program [10] 

biogas is compressed and fed into an absorption column, 

where carbon dioxide is removed from the gas 

stream by sorption into the washing liquid. Water and 

Genosorb® 1753 currently are state-of-the-art solvents. 

After passing a flash-drum, the solvent is 

regenerated in a desorption column where a stripping 

medium, which is ambient air in most cases, is 

inserted in order to lower CO 2 partial pressure in the 

gas phase and therefore enhance CO 2 desorption. 

Hence, oxygen and nitrogen are absorbed into the 

solvent and further on released in the actual absorption 

column into the biogas stream. 

Within the DVGW survey [8] the resulting oxygen 

contents were calculated on basis of process modeling 

tools, such as ASPEN Plus®. Hence, in a setup as shown in 

Figure 2, residual oxygen contents in a range of 0.5 

vol.-% up to 1.2 vol.-% were computed to end up in the 

upgraded biogas. Confirmation is given by recent 

biogas monitoring programs [10], where oxygen contents 

ranging from lower than 0.1 vol.-% up to 1.8 vol.-% 

have been reported, as shown in Figure 3. 

It is mandatory, that such high oxygen loads have 

to be removed prior to the injection into the high pressure 

gas grid. Figure 1 also shows possible installation 

locations ( ) for potential oxygen removal units. Two 

can seriously be taken under consideration, oxygen 

removal directly within the biogas plant or alterna- 



REPORTS 

Bunder-Tief 

Steinitz 

Ochtrup 

Werne-Stockum 

Broichweiden 

Reckrod 

Lampertheim 

Kienbaum 

Gas grid intersection 

points 

Ø Gas flow rate 

in m 3 /h (Winter) 

Ø Gas flow rate 

in m 3 /h (Summer) 

Kienbaum 768.000 315.000 

Steinitz 331.000 136.000 

Werne-Stockum 198.000 81.000 

Lampertheim 123.000 50.000 

Bunder-Tief 79.000 32.000 

Ochtrup 49.000 20.000 

Broichweiden Süd 37.000 15.000 

Reckrod 5.000 2.000 

No. of possible injecting plants 

200 

200 

Kienbaum 

Winter (01/2011) Summer (07/2011) 

Steinitz 

150 

100 

Werne-Stockum 

Lampertheim 

Bunder-Tief 

Ochtrup 

Broichweiden 

150 

100 

50 

Reckrod 

0 

50 

0 

100 1000 5000 10000 

100 1000 5000 10000 

Oxygen content in the biogas in ppmv 

Oxygen content in the biogas in ppmv 

No. of possible injecting plants 

Figure 4. Assessment of the possible number of injection plants at representative intersection points as a 

function of residual oxygen content in the biogas 

tively at the point of recompression. A third option 

(neglecting the violation of the threshold value in the 

actual grid piping) would be to install the removal 

units prior to gas storages and at points of cross border 

gas exchange, respectively. However, this option 

suffers the strong dilution of oxygen in combination 

with the large gas flow rates, which both result in 

excessively large removal systems. 

Removal of oxygen directly on-site of biogas plants 

has the advantage, that synergy effects can be incorporated. 

In case several biogas plants inject their gas 

to one and the same distribution network, removal of 

oxygen is an option at the point of recompression. 

Hence, within this option additional process steps, 

such as drying, adaption of calorific value e. g. would 

need to be installed. 

3. AVOIDANCE VERSUS REMOVAL OF 

OXYGEN 

Despite of the sometimes relative large oxygen content in 

biogas, it is often misleadingly expected, that the threshold 

value of 10 ppmv oxygen can simply be met by diluting 

biogas with natural gas in the gas grid. This misjudgment is 

due to the large flow capacity of the gas transportation network. 

Against this background some simplified calculations 

were performed, taking the ordinary gas flow rates of representative 

intersection points in Germany’s gas grid infrastructure 

into consideration. Additionally, the flow rates in the winter 

and in the summer period were incorporated (see Figure 4) 

to give an impression on the maximum number of biogas 

plants that could possibly inject their gas until the threshold 

value of 10 ppmv is exceeded at the selected locations. 


REPORTS 


As can be seen in Figure 4, the oxygen problem can 

hardly be ignored. Especially in comparison with the 

aforementioned goals of substituting 6 billion m 3 STP of 

the natural gas demand by the year 2020, which would 

mean to install a total number of about 1.500 plants with 

an average biogas capacity of about 500 m³/h (STP). 

Mainly in the summer time, when the natural gas consumption 

is comparatively low and the amount of recompressed 

biogas is expected to be high, only few plants 

could inject their gas at which only very low oxygen 

contents of about 100 ppmv would be tolerable. A more 

realistic assumption of an average oxygen content of 

about 1.000 pmmv results in total quantity of about 10 

plants in summer and about 30 plants in winter, not taking 

the expected reduction of natural gas consumption 

nor local oxygen concentrations into account. Biogas 

plants with physical scrubbers and oxygen contents of 

about 5.000 ppmv could hardly inject any biogas into the 

transportation network, regardless of the season. 

4. STATE-OF-THE-ART TECHNOLOGIES 

FOR OXYGEN REMOVAL 

There are several ways to remove oxygen from gas 

streams. Besides some physical processes, such as sorption 

on molecular sieves or activated carbon, membrane 

separation or certain cryogenic solutions, only 

chemical processes are suitable to meet the requirements 

of a residual oxygen content of 10 ppmv. This is 

due to the fact that physical processes all unite in the 

necessity for a distinct concentration gradient, which is 

comparatively small in the case of the removal of oxygen 

from biogas. This prohibits any physical process to 

become economically feasible. 

However some chemical processes are commercially 

available and can be denoted as state-of-the-art technologies. 

There are mainly two options. The first is a 

continuous adsorption based processes, commonly 

using copper (eq. 2) or chromium as adsorption materials. 

These are placed in at least two or more fixed bed 

adsorption columns, necessary for alternating loading 

and regeneration. 

2 Cu + O 2 → 2 CuO (2) 

For regeneration, a reducing agent is required. Usually 

hydrogen is applied (eq. 3), which is not available at 

biogas plants and therefor has to be applied from an 

external source. 

CuO + H 2 → Cu + H 2O (3) 

For copper based adsorption processes a minimum operation 

temperature of 150 °C needs to be maintained. The 

maximum temperature is limited to 250 °C in order to 

avoid thermal damage of the bed material. As a result of 

the strong exothermic oxidation reaction, the oxygen 

amount in the feed gas is limited to 1 vol.-%. Besides, the 

actual oxygen uptake capacity of commercially available 

adsorbents is comparatively low with 5 - 10 l/kg (STP). For 

these reasons, suchlike processes are typically applied in 

advance of oxygen sensitive applications in the context 

of fine purification where low oxygen contents (


REPORTS 

Table 1. Overview over state-of-the-art technologies and comparison with new catalytic approaches for 

removal of oxygen from biogas 

Adsorption 

State-of-the-art 

Oxidation of 

Hydrogen 

Oxidation of 

Methane 

New approaches 

Oxidation of LPG 

(Reforming) 

+ H2/CO Ox. 

T in °C 150 - 250 80 250 - 350 200 - 300 800 / 250 

O2: Fuel Ratio 1:2 1:2 2:1 5,5:1 2:1 

Equipment 

Requirements 

↑ ↓ ↓ → → 

Process Scheme 

Investment -- ++ + + - 

Operating Costs - - + 0 0 

Alternating 

Loadings 

+ 0 ++ 0 - 

vance in industry for catalytic oxidation units, operating in 

excess fuel conditions, especially when methane is to be 

incorporated as a reducing agent for oxygen. 

The third option represents an in-situ generation of 

hydrogen and carbon monoxide out of methane (eq. 7, 8). 

This is an attempt to incorporate a minor partial flow of 

biogas, however, reform it completely and afterwards mix 

it with the actual biogas stream. Hence hydrogen and 

carbon monoxide are available for oxygen removal (eq. 4, 

9). In contrast to the first two options, a small second catalytic 

reaction unit, operated at high temperatures is necessary. 

The typical operation temperature of a catalytic 

reforming unit for natural gas (commercially performed 

with a nickel catalyst) in a technical scale is about 800 °C. 

CH 4 + H 2O → CO + 3 H 2 (7) 

CH 4 + CO 2 → 2 CO + 2 H 2 (8) 

Table 1 also shows some qualitative evaluation of the 

presented alternatives. Besides the required temperatures 

and the oxygen to fuel ratio, an evaluation of equipment 

requirements, pricing and process dynamics is 

given. The comparison of the most promising alternative: 

the utilization of methane vs. the state-of-the-art technology 

oxidation of hydrogen is of special interest. As a 

consequence of the higher reaction temperature a larger 

heat exchanger is needed in the methane case, which 

results in higher investment. Conversely, the lower fuel 

costs for methane lead to lower operating costs. For the 

hydrogen fuel costs, delivery, storage, injection and mixing 

with the biogas stream also have to be incorporated. 

Concerning variation of oxygen contents, the utilization 

of methane is the most promising alternative, because 

methane is available anyhow and therefor the fuel concentration 

has not to be adapted to the oxygen content. 

At present, a DVGW-research project [9] is undertaken, 

focusing on the development of design data for a catalytic 

oxygen removal unit by oxidation of methane. For 

this purpose, a lab scale catalytic test rig was built. Key 

aspect of the ongoing experiments is the identification of 

an appropriate kinetic approach as well as the determination 

of kinetic data for a set of reference catalysts on 

noble metal basis for typical biogas compositions and 

working pressures. 

Some of the results are given in Figure 5 [12], 

which shows a variation of the oxygen content in a 

balance of methane in a range of 0.1 vol.-% to 0.8 

vol.-% (blue curves) and a variation of operation pressure 

from 1 bar to 10 bar (red curves) for a platinum 

catalyst. As a typical behavior, it can be observed, 

that an increase of the oxygen content in the feed 

results in a higher temperature, necessary for the 

desirable complete conversion of oxygen. At ambient 

pressure and the given residence time, this temperature 

ranges between 250 °C and 350 °C. In contrary, 


REPORTS 


Figure 5. Oxygen conversion in the lab scale test rig 

at Engler-Bunte-Institute as a function of 

feed composition and system pressure 

partial pressure in the gas has a crucial impact on the 

reaction rate – even though methane is available in 

large excess. This seems surprisingly at first. 

In literature the reaction mechanism for the oxidation 

of methane is described by the so called Eley-Rideal 

mechanism [13, 14], which indeed assumes methane to 

have a limiting influence on reaction rate due to weak 

absorption interactions with the catalytic surface. Eley- 

Rideal presumes oxygen to be sufficiently absorbed on 

the catalytic surface at any time. However, these observations 

are based on examinations performed in excess 

of air or oxygen. Thanks to the new experiments, the 

validity of Eley-Rideal for the oxidation of methane can 

be extended to oxygen partial pressures as low as 

approximately 1 mbar. 

In addition to the examinations with methane, a variation 

of fuel gases was carried out. As an overview, 

Figure 6 [12] shows the relative stability of the potential 

fuel components for oxygen removal. For reasons of 

comparability, the fuel gas content in the feed gas was 

defined to be 0.25 vol.-% for all fuels. 

Methane exhibits the highest stability. Therefor the 

highest reaction temperature is necessary. Higher 

hydrocarbons follow the sequence: ethane > propane > 

butane. Carbon monoxide lies between propane and 

butane. Hydrogen features the highest reactivity and 

allows a complete conversion of 1.000 ppmv of oxygen 

at about 50 °C. 

6. PERSPECTIVES 

Further on, experiments with other catalysts will be 

carried out in order to identify more cost effective 

materials which still feature sufficient activity for the 

oxidation of methane. Thereafter, sulfur tolerance in 

respect to contamination of the feed gas with hydrogen 

sulfide will be regarded, before the test rig will 

be moved directly on-site of a biogas plant and fed 

with actual biogas. 

ACKNOWLEDGEMENTS 

Figure 6. Relative comparison of the activity of 

different fuel gases on the conversion of 

oxygen 

when traces of methane are to be removed from air 

streams, a minimum of 400 °C is usually required with 

platinum catalysts. Taking into account the variation 

of pressure leads to the conclusion, that the methane 

The authors are thankful for the funding from DVGW 

(German Technical and Scientific Association for Gas 

and Water). 

REFERENCES 

[1] Gesetz zur Neuregelung des Rechts der Erneuerbaren 

Energien im Strombereich, Artikel 1: Gesetz für 

den Vorrang Erneuerbarer Energien (EEG). Bundesgesetzblatt 

2008, Teil I, Nr. 49 

[2] Gasnetzzugangsverordnung; Teil 6 Biogas, § 31 

(09/2010) 



REPORTS 

[3] Köppel, W; Graf, F.: Results of a DVGW Biogas Monitoring 

Program; gwf-Gas|Erdgas International 151 

(2010) 13, 38-46 

[4] DVGW-Arbeitsblatt G 260: Gasbeschaffenheit. Jan 2012 

[5] EASEE-Gas: CBP 2005-001/02; Harmonization of 

Natural Gas Quality 

[6] Groneman, U. et al.: Oxygen Content in Natural Gas 

Infrastructure; gwf-Gas|Erdgas International 151 

(2010) 13, 26-32 

[7] Wagner, M. et al.: DGMK Research Report 756; Influence 

of Bio-methane and Hydrogen on the Microbiology 

of Underground Gas Storage – Literature 

Study (2013) 

[8] Köppel, W. et al.: Vermeidung und Entfernung von 

Sauerstoff bei der Einspeisung von Biogas in das Erdgasnetz. 

gwf-Gas|Erdgas 153 (2012) 1, 2-11 

[9] DVGW-Forschungsvorhaben G1 05 10 F: Entfernung 

von Sauerstoff aus Biogas mittels katalytischer Oxidation 

von Methan und oxidativer Umsetzung an 

Eisensulfiden. (2013-2014) 

[10] Köppel et al.: Abschlussbericht DVGW-Forschungsvorhaben 

G 1 03 10: Monitoring Biogas II. (09/2013) 

[11] Graf, F.; Bajohr, S.: Biogas – Erzeugung, Aufbereitung, 

Einspeisung. München: Oldenbourg Industrieverlag 

(2011) 

[12] Frankovsky, R.; Ortloff, F.: Katalytische Entfernung von 

Sauerstoff aus Biogas mittels Oxidation von Methan. 

Diplomarbeit, KIT (2013) 

[13] Knebel, F. W.: Erdgasvorwärmung durch direkte katalytische 

Oxidation; Dissertation, Universität Karlsruhe 

(TH) (2000) 

[14] Reinke, M.: Katalytisch stabilisierte Verbrennung von 

CH 4/Luft-Gemischen und H 2O- und CO 2-verdünnten 

CH 4/Luft-Gemischen über Platin unter Hochdruckbedingungen; 

Dissertation, ETH Zürich (2005) 

AUTHORS 

Dipl.-Ing. Felix Ortloff 

DVGW Research Center at Engler-Bunte- 

Institut (DVGW-EBI) Karlsruhe Institute of 

Technology (KIT), 

Karlsruhe | Germany 

Phone: + 49 721 608 4 7071 

E-mail: felix.ortloff@kit.edu 

Dr. Frank Graf 

DVGW Research Center at Engler-Bunte- 

Institut (DVGW-EBI) Karlsruhe Institute of 

Technology (KIT), 


Prof. Dr. Thomas Kolb 

Engler-Bunte-Institute, Division of Fuel 

Chemistry and Technology (EBI-CEB) 

Karlsruhe Institute of Technology (KIT), 



ASSOCIATIONS 

ENTSOG launches Transparency Platform 

The transparency guidelines and congestion management 

procedures (Chapter 3 of Annex 1 to Regulation 

(EC) No 715/2009 and its amendments) require ENTSOG 

to provide a Union-wide central platform, where all gas 

Transmission System Operators can make their relevant 

data publicly available. 

ENTSOG has been working, along with its service providers, 

on upgrading its Transparency Platform, operating since 

2009 on a voluntary basis. Since 1 st of October, onwards 41 

TSOs can use the platform (www.gas-roads.eu) to upload 

necessary data and information 

and make them available to all 

market participants. The platform contains technical and 

commercial information, made available through tables and 

maps, needed by all the users of gas networks. 

ENTSOG will continue to work on further improvements 

and user friendliness of this platform and the 

related content. However, for the time being, it is the TSOs 

responsibility to upload their data correctly, consistently 

and in a timely manner. 

IGU launches the Wholesale Gas Price Survey - 2013 Edition 

The report on "Wholesale Gas Price Formation" first 

published in June 2012 for the World Gas Conference 

in Kuala Lumpur, has now been updated by Study Group 2 

of the IGU Strategy Committee (PGCB). 

Historically, gas prices have not been in the news to 

the same extent as oil prices. This is changing as the 

share of gas in global energy consumption continues to 

increase, volumes of internationally traded gas are 

greater than ever before and different price formation 

mechanisms have had serious commercial implications 

both for producing and consuming nations. The rapid 

growth in shale gas production in North America and 

fundamental shifts in LNG supply patterns across the 

global gas market relate to strong intercontinental linkages 

between supply, demand and price. At the same 

time this report sets out the large variations in wholesale 

gas prices across the world that result from the different 

prevailing price formation mechanisms. 

The first and the updated reports of the global 

review of wholesale gas price levels and price formation 

mechanisms are also available on the IGU website - 

www.igu.org. 

ENTSOG and GIE publish 

Capacity Map 2013 and System 

Development Map 2012 

The European Network of Transmission System Operators 

for Gas (ENTSOG), in cooperation with Gas Infrastructure 

Europe (GIE), has published the third edition of 

the map dedicated to system development matters and 

covering the year 2012. At the same time, ENTSOG releases 

the 2013 edition of its capacity map and GIE publishes the 

revised 2013 edition of its storage and LNG maps. 

Through these maps, ENTSOG and GIE, together with 

their respective members, go beyond the day-to-day 

transparency and further contribute to the analysis of the 

dynamics of the European gas market. 

The new edition of the System Development Map 

provides a graphical representation of infrastructure 

projects considered by ENTSOG in its TYNDP 2013- 

2022 assessment of the infrastructure-related market 

integration as well as of demand and supply developments 

in 2012. 

ENTSOG and GIE are committed to further enhance 

the map features in the future and welcome feedback on 

this from stakeholders. 

The maps are available for download at http://www. 

entsog.eu/maps and http://www.gie.eu/maps_data. 


ASSOCIATIONS 

Eurogas predicts stable EU gas demand for 2013 

Gas demand across the European Union is expected 

to remain relatively stable in 2013 compared with 

2012, according to the latest forecast from Eurogas. An 

increase in demand of 2.6% was recorded in the first half 

of 2013 compared with the same period in 2012. 

These latest estimates are the result of an annual survey 

covering 90% of the EU gas 

market and carried out by Eurogas, 

the association representing 

the European gas wholesale, 

retail and distribution sector, 

among its members. According 

to Eurogas, the slight increase in 

EU gas demand recorded for the 

first six months of 2013 can be 

attributed to the long winter and low temperatures. 

Across the EU such colder than usual weather conditions, 

particularly in March and May 2013, led to an increase in 

gas consumption for heating. However, even if the exceptionally 

long winter raised gas demand, other factors 

have continued to negatively affect demand. 

While industrial production showed signs of recovery 

in some member states, important cross-country differences 

persist and gas demand from the industrial sector 

only registered limited increase in the EU as a whole. 

Gas use in power generation has continued to slide as a 

result of unfavourable market fundamentals. The low coal 

price and a weak carbon price continued to favour coal 

generation. The effects of the economic crisis and poor 

growth continued to result in weak final power demand. In 

addition, the growing share of electricity produced from 

renewables and a relatively high hydroelectricity production 

also reduced the demand for gas in power generation. 

Such factors are still expected 

to influence demand in the 

second half of the year. 

Early indications from the 

Eurogas data suggest that gas 

demand in Europe is likely to 

remain stable throughout 2013, 

registering a slight increase of 

1% compared with 2012. 

Despite the small increase, demand in the second half of 

2013 will remain under pressure as gas use in the power sector 

is expected to remain weak. This issue, coupled with the 

still sluggish economic recovery across the EU will have a 

detrimental impact on gas demand in the rest of 2013. With 

regard to heating demand, forecasts for the second part of 

the year in normal weather conditions do not point to any 

significant increase. 

On this basis, taking 2013 as a whole, gas demand 

would correspond to an EU & Switzerland annual consumption 

of about 5 130 terawatt-hours or 475 billion 

cubic metres. 

Shale gas chemical disclosure site 

reaches 10-well milestone 

NGSFacts.org, the voluntary oil & gas industry natural 

gas from shale well disclosure website, has published 

its tenth well disclosure sheet. 

NGS Facts is a web-based European chemical disclosure 

platform. Launched in June 2013 by the International 

Association of Oil and Gas Producers (OGP), it gives public 

access to information about the contents of the fracturing 

fluids being used for shale wells in Europe. 

OGP is reaching out to increase operator participation. 

In order to participate they must commit to submitting 

data in a timely manner for all of their EEAlocated 

NGS-directed hydraulically fractured wells. 

A similar website, FracFocus, provides information 

about the contents of the fracturing fluids being used in 

US and Canadian shale gas wells. 

The ten well sites featured on 

NGSFacts.org are all in Poland. The 

data come from Conoco Phillips/ 

Lane Energy, ExxonMobil Exploration 

and Production Poland Sp. 

Zoo, Marathon Oil Polska and 

Chevron Polska Energy Resources. 

OGP is pleased to announce that Shale Gas Europe 

and Eurometaux have formally indicated their support 

for the initiative. 

In addition to providing well disclosure information, 

NGSFacts answers frequently asked questions about the 

exploration and production of unconventional gas. The 

queries cover central topics such as water, chemicals, 

seismicity and greenhouse gas. 


PRODUCTS & SERVICES 

Software package offers versatile product monitoring 

Emco Wheaton has unveiled an innovative new software 

package Drawbar + which will automatically 

monitor product levels in individual compartments of 

tankers. The software offers the further advantage of being 

able to simultaneously monitor levels within any additional 

multi-compartmental draw bar trailer which may be connected 

to and towed by a tanker mid-application. Ineffective 

monitoring of compartments can result in inaccurate 

distribution and product recognition at the point of delivery, 

potentially affecting profit margins and customer relations. 

When adding a multi-compartment drawbar trailer, 

it can be even more difficult and time consuming to keep 

track. The new Drawbar + from Emco Wheaton, is an 

upgrade of its Compartment Volume Monitoring software 

which automatically detects any addition of compartments 

and alters its display to accommodate them. 

If a two-compartment draw bar trailer is connected to a 

tanker with four compartments, Drawbar + will immediately 

begin to monitor and display the product levels in all six 

compartments. During loading, details are entered into the 

litre counter and compartment contents are displayed 

graphically and numerically. Drawbar + automatically displays 

the name, location and volume of the product in each 

compartment throughout transportation. Helping with 

accurate distribution, the volume is recalculated throughout 

the delivery process and any retained product is displayed. 

Contact: 

Emco Wheaton 

www.emcowheaton.com 

I-Test ensures gas detectors are compliant 

The new Crowcon I-Test bump testing and calibration station 

is designed specifically to test and verify that Crowcon’s 

Gas-Pro portable gas detectors are in a compliant state. 

Bump testing (gas testing) standards globally are becoming 

ever-stricter and the demands on fleet managers to control 

bump and calibration records are increasingly stringent. The 

I-Test simplifies this process as much as possible. 

To start with, there’s no need to turn the test gas on 

and off – a flow regulator automatically pulls in the correct 

amount and concentration of gas 

for each bump. The I-Test also starts 

automatically as soon as a Gas-Pro 

detector is inserted without the need 

to press any buttons. The device then 

verifies that all gas sensors are 

responding to a known value of gas 

and that the filters are clear and good 

for use. It also tests that audible and visual alarms are 

working, giving the user full confidence that a unit is 

compliant for site use. In addition, the I-Test informs the 

operator if a gas cylinder is empty or has expired. 

The accompanying I-Test Manager software tracks 

which Gas-Pro units need calibrating and allows storage, 

interrogation and convenient presentation of large 

amounts of bump testing data. Calibration certificates are 

automatically created and stored and many different 

types of reports and graphs can be created for easy interpretation. 

All this information is then easily accessible for 

audit and compliance purposes. 

Contact: 

Crowcon Detection Instruments Limited 

E-Mail: eu@crowcon.com 

www.crowcon.com 


PRODUCTS & SERVICES 

New synergie pipeline enables GIS integration 

DNV Software’s new release of Synergi Pipeline software 

includes GIS integration, providing pipeline 

operators better analyses and decision-making based 

on geographically referenced and visualized data via 

the web interface. 

Obtaining and managing correct and valid information 

about a pipeline’s risk and condition, including linked 

geographic information, is a constant challenge in integrity 

management. Synergi Pipeline, DNV’s pipeline integrity 

management and risk assessment software solution, 

produces efficient information management and data 

reliability while providing consistent application of integrity 

procedures. 

The new version of Synergi Pipeline (6.2) provides 

an interface with clear, intuitive visualization 

both of risk and also technical and operational status 

of offshore and onshore pipelines. The visualization 

is more extensive through integration with the 

ArcGIS server, allowing the user to work with all 

pipeline data using a web-based viewer. The tool 

(EsriViewer) shows a map view of the pipelines with 

configurable data layers, such as risk, pipeline features, 

inspection data and analysis results and tools 

to select and filter the data. 

Another main new feature of Synergi Pipeline is the 

improved traceability. Users can now understand the 

background for activities. Furthermore, the analysis 

functionality has been improved allowing identification 

of interacting corrosion defects, and remaining life analysis 

using both deterministic and probabilistic methodologies, 

enabling operators to plan mitigating actions 

more efficiently. 

Contact: 

DNV Software 

Are Føllesdal Tjønn 

E-mail: are.follesdal.tjonn@dnv.com 

www.dnv.com 

Multi-Gas flow 

totalizer software for 

QuadraTherm® 640i/780i 

Sierra Instruments releases new free flow totalizer software 

module for their QuadraTherm® 640i/780i mass 

flow meter. Through their QuadraTherm Software Interface 

Program (SIP), end users now have an management 

tool to totalize and monetize all gases with one instrument. 

The flow totalizer software module leverages 

QuadraTherm’s high accuracy (+/- 0.5% of full scale) to 

give end users the most accurate totalization of multiple 

gases from an industrial flow meter. 

There are four totalizers visible on the user interface 

screen of the SIP software. The user selects one to be 

active. Each totalizer is independent of the others, allowing 

users to totalize one gas, then switch and totalize 

another gas. End users can switch back to their previous 

gas to begin totalizing flow with the previous flow total 

maintained or reset if necessary. 

Contact: 

Sierra Instruments 

www.sierrainstruments.com 


DIARY 

• European Gas Conference Vienna 2014 

27.–31.1.2014, Vienna, Austria 

www.europeangas-conference.com 

• E-world energy & water 

11-13.2.2014, Essen 

www.e-world-essen.com 

• Pipeline Coating 2014 

24-26.2.2014, Vienna, Austria 

www.amiplastics.com 

• Gastech 2014 

24-27.3.2014, Seoul, South Korea 

www.gastechkorea.com 

• Hannover Messe 

7-11.4.2014, Hannover, Germany 

www.hannovermesse.de 

• 9 th Pipeline Technology Conference 

12-14.5.2014, Berlin, Germany 

www.pipeline-conference.com 

• 124 th ÖVGW Annual Conference 

21-22.5.2014, Salzburg, Austria 

www.ovgw.de 

• EGPFE – European Gas Processing Show 2014 

14-16.5.2014, Dusseldorf, Germany 

www.egpfe.com 

• European Gas Production Forum and Exhibition 

4-6.6-2014, Dusseldorf, Germany 

www.egpfe.com 

• 22 th European Biomass Conference and Exhibition 

26.6.2014, Hamburg, Germany 

www.conference-biomass.com 

• KIOGE 2014 

7-11-10.2014, Almaty, Kazakstan 

www.kioge.com 


uyer’s guide 

A close-up view of the 

international gas business 

Gas transmission and distribution 

Gas-pressure control and gas 

measurement 

Gas quality and gas use 

Gas suppliers 

Trade and information technology 

DVGW-certified companies 

Please contact 

Uwe Lätsch 

Phone: +49 89 2035366-77 

Fax: +49 89 2035366-99 

E-mail: laetsch@di-verlag.de 

www.gas-for-energy.com

2013 


Buyer’s Guide 

Pipe penetrations 

Pipelines and pipeline accessories 

Fittings and accessories 

Fittings 

Corrosion protection 

Active corrosion protection 



2013 

Active corrosion protection 

Corrosion protection 


Passive corrosion protection 

Gas-pressure control and Gas measurement 

Gas-measuring equipment 


2013 

Gas quality and Gas use 


Gas preparation 

Filtration 

Gas storage, LNG 

Gas compression 


dVGW-certified companies 

2013 

Pipe and pipeline engineering 

Filters 


Gas-measuring equipment 

System servicing 


The international magazine 

for industrial furnaces, 

heat treatment plants 

and equipment 

The technical journal for the entire field of industrial furnace 

and heat treatment engineering, thermal plants, systems 

and processes. 

The publication delivers comprehensive information, 

in full technical detail, on developments and solutions 

in thermal process engineering for industrial applications. 

Select the subscription offer that you prefer: 

• print 

• e-paper 

• print + e-paper 

on the annual 

Save 25% subscription 

www.heatprocessing-online.com 

heat processing is published by Vulkan-Verlag GmbH, Huyssenallee 52-56, 45128 Essen, Germany 


FUTURE 

Order now by fax: +49 931 / 4170-494 or send in a letter 


Yes, I want to read heat processing on a regular basis. During the first year I will benefit from a 25% 

discount on the annual subscription fees. I subscribe to the technical trade journal for at least one 

year (4 issues) 

as a printed magazine at the annual price 

of € 127.50 plus shipping (€ 12.00 within 

Germany / € 14.00 outside of Germany) 

as an e-paper magazine (single user) at 

the annual price of € 127.50. 



(within Germany) / € 179.75 (outside of 

Germany) incl. shipping. 

Special offer for students (proof of entitlement) 

as a printed magazine at the annual price of 

€ 63.75 plus shipping (€ 12.00 within Germany / 

€ 14.00 outside of Germany). 

as an e-paper magazine (single user) 

at the annual price of € 63.75. 



(within Germany) / € 96.88 (outside of Germany) 

incl. shipping. 




Country, postalcode, town 

Reply / Antwort 

Readers’ Service heat processing 

P.O. Box 91 61 

97091 Wurzburg 

GERMANY 

Phone 

E-Mail 


Fax 


to Readers’ Service heat processing, P.O. Box 91 61, 97091 Wurzburg, Germany. After the first period the agreement can 

be terminated in writing with 2 months notice to the end of each year. In order to accomplish your request and for communication 

purposes your personal data are being recorded and stored. 



This approval may be withdrawn at any time. 

✘ 


PAHEAT2014

IMPRINT AND INDEX OF ADVERTISERS 

IMPRINT 

gas for energy 

Magazine for Smart Gas Technologies, Infrastructure and Utilisation 

Publication of 

Farecogaz – Association of European 

Manufacturers of Gas Meters, Gas 

Pressure Regulators, Safety Devices 

and Stations 

GERG – Group Europeen de 

Recherches Gazieres 

GIE – Gas Infrastructure Europe 

Marcogaz – Technical Association of 

the European Natural Gas Industry 

Editorial team: 

Managing Editor: Volker Trenkle 


Arnulfstraße 124 

80636 München 

Phone +49 89 203 53 66-56 

Fax: +49 89 203 53 66-99 

E-Mail: trenkle@di-verlag.de 

Editor: Elisabeth Terplan 

Phone +49 89 203 53 66-43 

Fax: +49 89 203 53 66-99 

E-Mail: terplan@di-verlag.de 

Office: Birgit Lenz 

Phone +49 89 203 53 66-23 

Fax: +49 89 203 53 66-99 

E-Mail: lenz@di-verlag.de 

Publishing House: 


Arnulfstraße 124 

80636 München 

Phone +49 89 203 53 66-0 

Fax: +49 89 203 53 66-99 

E-Mail: info@di-verlag.de 

Internet: www.gas-for-energy.com 

Head of Division: 

Stephan Schalm 

Managing Directors: 

Carsten Augsburger, 

Jürgen Franke 

Advertising: 

Advertising Sales: Uwe Lätsch 

Phone +49 89 203 53 66-77 

Fax: +49 89 203 53 66-99 

E-Mail: laetsch@di-verlag.de 

Advertising Administration: 

Eva Feil 

Phone +49 89 203 53 66-11 

Fax: +49 89 203 53 66-99 

E-Mail: feil@di-verlag.de 

Layout: 

Carolin Sehnem 

E-Mail: sehnem@di-verlag.de 

Rates: 

gas for energy is published three 

times a year. 

• Subscription printed magazine 

inside Germany: € 149,– 

(€ 140,– + € 9,– shipping) 

• Subscription printed magazine 

outside Germany: € 150,50 

(€ 140,– + € 10,50,– shipping) 

• Subscription e-paper magazine: 

€ 140,– 

As a subscriber of the periodical 

gwf Gas | Erdgas, or as a member of 

Farecogaz, GERG, GIE or Marcogaz, 

gas for energy is being delivered at a 

prize of € 112,- (e-paper) or at a price 

of € 112,– plus shipping (print). 

Subscriptions/Single Copy Sales: 

Readers’ Service gas for energy 

DataM-Services GmbH 

Marcus Zepmeisel 

Franz-Horn-Str. 2 

97082 Würzburg, Germany 

E-Mail: leserservice@di-verlag.de 

Phone: +49 931 4170-459 

Fax: +49 931 4170-494 

The magazine and all the contributions 

and illustrations contained 

therein are secured by copyright. With 

the exception of the legally permitted 

instances, any utilisation without the 

express permission of the publisher 

will be punished at law. The opinions 

contained in signed articles do not 

necessarily reflect the opinion of the 

publisher. 

Printed by 

Druckerei Chmielorz GmbH 

Ostring 13 

65205 Wiesbaden-Nordenstadt 

Germany 

DIV Deutscher Industrieverlag GmbH, 

München 

Printed in Germany 

INDEX OF ADVERTISERS 

Company 

Page 

DENSO GmbH, Leverkusen 21 

Euroforum Deutschland SE, 

Düsseldorf 11 

E-world energy & water GmbH, Essen 9 

Fachverband Biogas e.V., Freising 13 

Ing.Büro Fischer-Uhrig, Berlin 53 

Company 

Page 

KÖTTER Consulting Engineers 

GmbH & Co.KG, Rheine 15 

Messe Düsseldorf GmbH, Düsseldorf 17 

REECO GmbH, Reutlingen 19 

RMG GmbH, Kassel 

Cover 

Buyers Guide 71 - 75

The Gas Engineer’s 

Dictionary 

Supply Infrastructure from A to Z 

The Gas Engineer’s Dictionary will be a standard work for all aspects of 

construction, operation and maintenance of gas grids. 

This dictionary is an entirely new designed reference book for both engineers 

with professional experience and students of supply engineering. The opus 

contains the world of supply infrastructure in a series of detailed professional 

articles dealing with main points like the following: 

• biogas • compressor stations • conditioning 

• corrosion protection • dispatching • gas properties 

• grid layout • LNG • odorization 

• metering • pressure regulation • safety devices 

• storages 

Editors: K. Homann, R. Reimert, B. Klocke 

1 st edition 2013, 452 pages with additional information and complete ebook, 

hardcover, ISBN: 978-3-8356-3214-1 

Price € 160,– 

DIV Deutscher Industrieverlag GmbH, Arnulfstr. 124, 80636 München 

www.di-verlag.de 

Order now! 


FUTURE 

Order now by fax: +49 201 / 820 02-34 or send in a letter 


Yes, I place a firm order for the technical book. Please send 

— copies of the The Gas Engineer’s Dictionary 

– Supply Infrastructure from A to Z. 

1st edition 2013, plus ebook (ISBN: 978-3-8356-3214-1) 

at the price of € 160,- (plus postage and packing extra) 




Country, Postalcode, Town 

reply / Antwort 

Vulkan-Verlag GmbH 

Versandbuchhandlung 

Postfach 10 39 62 

45039 Essen 

GERMANY 

Phone 

E-Mail 


Fax 


to Vulkan Verlag GmbH, Versandbuchhandlung, Postfach 10 39 62, 45039 essen, Germany. 



this approval may be withdrawn at any time. 


PATGED2013

gas for energy Reliability matters (Vorschau)

You also want an ePaper? Increase the reach of your titles

Delete template?

Save as template?