The Methaforming technology allows oil refiners and gasoline blenders to make Euro-4 and -5 compliant
high octane gasoline at 1/3 of the current level of costs and greenhouse gas emissions. The technology is
proven with a recent launch of a commercial unit and more than 7 000 hours of lab plant tests. A top-tier
engineering company hired by a large refiner confirmed our claims, estimated profitability of Methaforming
as the highest of 12 technology options that were studied, with a large advantage over the second best
alternative. Customer interest from Canada, China, a few EU countries, India, Iraq, Kazakhstan, Russia,
Ukraine, USA, Uzbekistan. After the first 1.5 years of marketing (as of July 2017), 29 units in pipeline, incl.
for sophisticated large and mid-size Western refiners. Looking to raise $5-6m, have indications of interest
for $4m of that amount.
3. NGTS investment opportunity 11-17
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ā¢ Employing our proprietary technology, oil refiners can produce high octane gasoline at
1/3 of the current costs and CO2 emissions. Our capital-efficient, scalable business model
taps into a $1 trillion gasoline market, collecting 0.5-1 cent from every dollar of the
revenue from gasoline made with our technology.
ā¢ First commercial Methaformer launched in 2017 and is profitable for the refiner.
Contracts for feed-specific trials signed with 7 refiners from Canada, Russia, Kazakhstan,
Uzbekistan with a view to design and build Methaformers ranging in capacity from 10k
to 1.5 million tons per year.
ā¢ In discussions with a global engineering company to provide Methaforming technology
for processing GTL naphtha for their $3+bn GTL unit(s).
ā¢ The team has a track record of 10x exits, is supported by top notch advisors.
ā¢ Profit and IP center in Switzerland; R&D, engineering and sales support offices in
Houston, TX and Moscow, Russia. We are raising $2 million in equity to finance business
development including expansion into new markets. Additional investment opportunity
available for funding production and sale of micro-methaformers that may become
standalone micro-refineries in emerging markets.
Summary: Methaforming Technology
5. NGTS investment opportunity 11-17
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What is good about Methaforming for our clients?
Proprietary catalyst and processing technology
ā¢ Use cheaper feeds1 to make high octane gasoline
ā¢ Increase operating margins by over $200 per ton
ā¢ Reduce capital expenditures by up to $120/tpa2
ā¢ Reduce CO2 emissions by 112 kg per ton of feed3
ā¢ Profitable starting with 2k tons per year4.
1 Methaforming can use lower-value light naphtha and similar feeds with over 500 ppm of sulfur.
2 TPA - tons per year, a measure of processing capacity.
3 Depending on specific feed composition and available alternatives.
4 On a pre-tax basis. Net profitability depends on the tax regime in the chosen location.
Our clients make more money
and less CO2 per each ton of feed
A top-tier engineering company hired by a large refiner (who later became our
customer) confirmed our claims, estimated profitability of Methaforming as the
highest of 12 technology options that were studied, with a large advantage over
the second best alternative.
7. NGTS investment opportunity 11-17
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Case studies: A refinerās investment in
Methaforming can pay back in under a year
Main feed
(~75% by weight;
with dry FCC gas
as secondary
feed)
What refiners do with
this feed now
What we suggest
doing with this feed
instead
Methaforming advantage:
Margin
increase
CapEx impact ($/ton
of annual capacity)
Raffinate from
aromatics
extraction*
Blend directly into
gasoline pool, lowering
resulting octane and value Process in a newly
built Methaformer
before blending into
the gasoline pool
$ 200+/ton
$ 190/tpa to build the
Methaformer
Light virgin
naphtha
Process in an
isomerization unit with
recycle
$ 27/ton
Methaformer costs
$ 50/tpa less to build
Full range
naphtha
Process in a suite
consisting of HDS+CCR +
isomerization units
$ 71/ton
Methaformer costs
$ 120/tpa less to build
Process in a suite
consisting of HDS+ Semi-
regen reformer
Process in the HDS
converted into a
Methaformer
$ 125/ton
$ 23/tpa to convert
HDS into Methaformer
All numbers are based on calculations performed for specific refiners. Actual results for other situations
(different composition of feed, different capacity) may differ.
* An example of āorphanā, i.e. frequently undermonetized, stream. Other examples include Light
Virgin Naphtha, FCC light naphtha, naphthas from coker, visbreaker, etc.
13. NGTS investment opportunity 11-17
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With the first unit in operation, risks are reduced
Technology risk areas
ā¢ Catalyst
effectiveness and
run time
ā¢ Reactor design and
construction (wall
effects, local heat
pools, etc.)
ā¢ Process control
Business risk areas
ā¢ Client adoption
ā¢ Economics at
industrial scale
ā¢ Capital
requirements
ā¢ Effectiveness and run time of the catalyst proven beyond doubt: over 7,000
hours of tests with the present catalyst, actual refinery feeds. Earlier generation
of the catalyst in profitable commercial operation for over 10 years.
ā¢ Methaforming uses a simple fixed-bed reactor with pressures and temperatures
that are ordinary for oil processing equipment.
ā¢ These issues represent typical engineering tasks for oil processing equipment.
They will be studied and resolved during the operation of the first small units.
ā¢ Current sales pipeline and enthusiasm of prospective clients suggest rapid
expected adoption once the first units launch and operate for 3-6 months. Other
supporting factors:
- Large (3x) CapEx advantage over alternative technologies;
- High operating profitability and low payback period;
- Particular strength when processing highly paraffinic light oil fractions (e.g.
GTL naphtha, shale oil, condensate).
ā¢ Expected economics confirmed by the first months of operating the first unit.
ā¢ No need for NGTS investors to fund multi-million dollar demo units: clients are
making the investment.
Risk mitigation
16. NGTS investment opportunity 11-17
Leaders of the 20-strong team: chemical
science, engineering and business building
15
Denis Pchelintsev, Ph.D. (Engineering)
Founder, General Director of
NGTS-Eastern Europe
ā¢ Co-founder of a petrochemical startup (predecessor to NGTS),
exit at >10x in 2013, together with Alexei.
ā¢ With NGT group since its founding in 2006.
ā¢ Earlier ā CEO of NIPTIEP Science and Technology Institute.
ā¢ Invented and implemented an oil spill clean-up technology.
Alexei Beltyukov
Founder, CEO
ā¢ Entrepreneur, three profitable exits from ventures he founded,
incl. together with Denis. Founder of NGT group.
ā¢ Launched a $2bn railcar leasing company. Turned around 10
and sold 8 industrial companies, net IRR > 42% over 9 years.
ā¢ Earlier at McKinsey & Co.
Olga Malova, Ph.D. (Chemical Engineering)
Chief Catalyst Officer
ā¢ Experience in catalytic refining processes with Bayer and Eni.
ā¢ Author of 50+ publications and 30+ patents.
ā¢ Commercially implemented an earlier generation of the
catalyst: a 6k bpd (300k tpa) unit at a 300k bpd (15m tpa)
European refinery. Profitable commercial operations since
1998; investment paid back in under a year.
ā¢ Professor at Gubkin State University of Oil and Gas.
Ć Technology advancement.
Ć Strategy and business development,
Ć General management.
Ć Operations in E. Europe and Middle East,
Ć R&D strategy.
Stephen Sims
President of NGTS ā North America
ā¢ Career with major oil companies: Exxon, Citgo, ConocoPhillips.
ā¢ Technical manager at 15k bpd, 120k bpd, 200k bpd refineries.
Led strategy development for major refinery upgrades
(projects up to $4.5 billion).
ā¢ Sold two technology licensing businesses for $25 million.
ā¢ Energy Advisor at Houston Technology Center, Independent
refining consultant for the World Bank.
Ć Operations in North America,
Ć Sales support,
Ć IP strategy.
17. NGTS investment opportunity 11-17
Key advisors
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Martin van SickelsMarvin Rakow
ā¢ Author of Refining chapter for ASTM Fuels and Lubricants
Handbook, numerous technical journal publications.
ā¢ Author of 15 patents in refinery process and fuel product
improvement.
Held senior executive positions in tech
development, operations and sales at oil refineries
(Citgo), refining technology developers
(Hydrocarbon Research) and engineering
companies (Kesler Engineering).
Was member of Executive Committee, VP and
Chief Technology Officer at KBR, Inc. (a $7+
billion EPC company with a strong presence in
oil refining) and held other senior management
positions at KBR and its legacy companies.
Was responsible for all of KBRās licensed and special execution
technologies worldwide e.g. refining, GTL, synthetic fuels and
others. Responsible for KBR Technology Development Center;
member of the Inquiry Review and Pricing Committees and
Chairman of Technology Screening and Patent Committees.
ā¢ Author of 20 papers and published report chapters.
23. NGTS investment opportunity 11-17
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Unipol vs. Methaforming
Process Both: chemical processing of hydrocarbons, single process
4 licenses per year 6 licenses per year (projected)
Sources: Company data, The Freedonia Group, EIA, BP, OPEC.
Adoption rate
Market size:
ā¢ Of the underlying
commodity
ā¢ Of technology licensing
ā¢ $ 150-200 billion (gasoline that
can be made by Methaforming)
ā¢ Private deals, no data available
ā¢ $ 100-150 billion (polyethylene that
can be made by Unipol process)
ā¢ Private deals, no data available
Market growth (underlying commodity):
ā¢ Relative
ā¢ Absolute
Equity value at exit
Unipol Methaforming
>20% per annum4.0% per annum
$ 30-40 billion$ 4-6 billion
Compared to Unipol, NGT Synthesis operates in a market with a 7x faster absolute growth, with a
comparable projected adoption rate
$ 500 million (2013) ?
Economics CapEx 35% lower, OpEx 10%
lower than alternatives
CapEx 60+% lower, OpEx 60+%
lower than alternatives
Standalone process (= high CapEx,
long start-up process)
Part of refinery complex (= lower
CapEx, faster startup)
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Methaforming: Reasons to expect rapid adoption
Factor Comment
ā¢ Much lower CapEx relative to existing alternative
technologies.
ā¢ High internal rate of return and low payback period.
ā¢ Even stronger advantage when processing highly
paraffinic shale oil.
ā¢ Fall back mode available when processing orphan
streams, lowering perceived risk to refiners.
ā¢ Higher CapEx advantage than any other major oil refining
technology enjoyed over alternatives in the last 50 years.
ā¢ Attracts initial interest and supports ability to borrow and
raise equity.
ā¢ Should the share of shale oil in overall crude production
grow further (as expected), Methaforming will become
even more attractive to refiners.
ā¢ When initially considering Methaforming for processing
of orphan streams (e.g. raffinate from aromatics removal
unit), refiners find comfort in knowing that should the
process fail, they retain the option of resuming the prior
mode of operations without a major disruption.