engo general presentation

New Solutions for Gas Processing

ENGO Engineering Ltd.

+ 7 (495) 540 4636

+ 7 (495) 540 4637

[email protected]

www.engo3S.com

http://www.engo3s.com/

Overview

2

ENGO Engineering Ltd. has developed, patented worldwide, tested and implemented new technological solutions

for natural or associated gas processing in oil & gas industry

Typical Technology Applications

• Natural Gas Liquids (NGL) Recovery in projects of new gas plant construction or upgrade of existing plant

• Dew Point Control while gas conditioning in gas pipeline transportation projects

• CO2 Removal in projects of new gas field development with high CO2 content

The technology is based on SuperSonic Separation (3S-Technology) of natural gas

Scope of Capabilities

Process Flow

Modeling

Conceptual Design Manufacturing &

Supply

Startup &

Commissioning

On-Site

Supervision

СН4

С3+ From design of technical solution to implementation

Our engineering capabilities allow us to find the best solution for your project ensuring effective monetization of your gas resources and fast payback of your investments

Intellectual Property

PATENTS

• 10 patents in Russia

• 30 patents in: - China - USA - Canada - Australia - Malaysia - CIS countries - Indonesia - and other countries

• 15+ patents pending

• Exclusive license for application of 3S-Technology in Russia • All 3S-Technology inventors are employed by ENGO Engineering

1997

1998-1999

2001 Successful

tests

in Canada

3S-Technology Milestones

2004 Pilot testing in

West Siberia

(SIBUR)

2007 Commercial Unit

at Gubkinskoe field

(Rosneft)

First patents

Start of technology development

2009-2010 Successful Tests

at Zapolyarnoe field

(Gazprom)

2011 First Commercial Unit

in China

(PetroChina)

2013 Commercial Unit at

Vyngopurovsky Gas Plant

(SIBUR)

From first patents and pilot testing to commercial field proven installations

Continuous design improvements and innovations

Management Team

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Managing Director - Lev Bagirov, PhD, leads all 3S-technology development activities for the last 20 years. He is an expert in establishment of creative multidisciplinary teams to search, identify, develop, and monetize innovative technologies. Under his leadership, ENGO Engineering evolved from a group of enthusiasts into a world-recognized engineering company holding a leading position in natural gas treatment. Mr. Bagirov has 15 years of experience representing the company in front of financial and industrial institutions as well as top authorities’ officials, and established with the above bodies solid partnership relations

Executive Director - Konstantin Ryazantsev has 25 years of experience in oil & gas industry and he has participated in major recent oil & gas full field development projects in Russia, such ass Sakhalin-2, Shtokman, Kovykta, Verhnechonskoye. Working in major multinational oil companies he has acquired comprehensive knowledge of gas markets, new technologies development strategies, leadership competencies and team managerial skills.

Strategy Director- Vladimir Feygin, PhD, is one of the most well-recognized experts in world energy development and natural gas infrastructure. Holding top consulting and advisory positions within a number of leading Russian oil & gas companies and financial institutions, he brings his expertise into determination of long-term strategy of new and existing major gas projects establishment and development worldwide. As a leader of a number of international studies and teams as being co-speaker of the EU-Russia Gas Advisory Council, Mr. Feygin benefits a wide-spread contact network within the global gas industry. He is member of ENGO Team from its very beginning

Head of Marketing - Vasily Borisov has 8 years’ experience of leading 3S-technology marketing and sales activities. He overlooked all the latest company’s industrial installation projects through the whole projects’ lifecycle furnishing the chain of success stories. Mr. Borisov’s personal involvement and active professional contact network assured first ENGO Engineering CO2-extraction contracts’ conclusion in Asia Pacific region. Prior to his joining the team, Vasily worked for various Russian and International oil & gas ventures in management and marketing for 10 years, completing several medium and large-scale projects

Technical Director - Salavat Imaev, PhD, as one of the developers of 3S-technology who deals with gas dynamics the whole his professional career, he personally led successful completion of more than 15 of ENGO Engineering projects. An extraordinary strong technical team selected, brought, and managed by Mr. Imaev, secured tremendous progress in all theoretical and practical aspects of technology development and applications. Mr. Imaev is the author of 30+ research articles and publications in reputable international media dedicated to various aspects of gas aerodynamics

Head of Legal - Irina Nikiforova is a top professional in both Corporate and Patent law overlooking all IP protection and contract activities of the company. Thanks to Irina’s professionalism and energy, ENGO Engineering successfully protects their rights for 3S-technology and its applications by timely and comprehensive patent obtainment in more than 30 judicatures. Mrs. Nikiforova also leads corporate deal structuring and completion conduct, securing efficiency and transparency of company’s operations

Research & Development

Having strong engineering & design team and utilizing local testing facility or at customer location ENGO Engineering keeps continuous research & development activities in the following directions:

New areas of 3S-Technology application in oil & gas industry

Sour gas removal from natural gas

New optimized process schemes for gas processing

Offshore application specifics

Improvements in 3S-Separator design

8

Technology Principle Swirling Device Sub / Supersonic

Nozzle

Working Chamber

Diffusor for withdrawal

of gas-liquid mixture

Diffusers

~70-85% Sales gas

Nozzle configuration

depends on required level

of gas dehydration

~15-30% gas-liquid mixture

Design of working

chamber ensures

optimal separation of

gases and liquids

Configuration of diffusors is

selected for effective

pressure recovery

Guaranteed spin rate

over 100 000 G

Feed gas

(up to 20%

on liquid

mass)

Supersonic diffusor

Subsonic diffusor P1

T1 (°K)

(0.35 - 0.6) P1

(0.6 - 0.9) T1(°K)

(0.5 - 0.8) P1

For more information and to watch video click here

http://engo3s.com/3s-tehnology

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Advantages of 3S-Technology

Tolerance to low input pressure

Simplicity and no maintenance

Tolerance to relatively low gas flow

rates

Tolerance to liquid content in input gas - up

tо 50% mass.

Low capital and operating costs

P P

P P

P P

P

P P

JT Valve 3S-separator Turbo-expander

P

3S-Separator combines simplicity of JT valve and effectiveness of turbo-expander

10

Zapolyarnoe gas-condensate field

Customer: Gazprom

2009-2010

Capacity: 10000 nm3/h

Pinput/Poutput=125/76

Gubkinskoe and Severo-Komsomol’skoe gas-condensate field

Customer: Rosneft

Gubkinskoe: 2007



Severo-Komsomol’skoe:.2012



Muravlenkovskiy Gas Plant

Customer: Sibur

2004-2005



Talimi (PetroChina)

2011



Application Geography

Dabey (PetroChina) 2015

Capacity : 43800 nm3/h

Pinput/Poutput =118/90

Recent Projects Examples VYNGAPUROVSKOE FIELD, SIBUR NEW GAS PROCESSING PLANT

GUBKINSKOE FIELD, ROSNEFT EXISTING GAS PROCESSING PLANT UPGRADE PROJECT

SEVERO-KOMSOMOLSKOE FIELD, ROSNEFT EXISTING GAS PROCESSING PLANT UPGRADE PROJECT

TARIMI FIELD, PЕTROCHINA EXISTING GAS PROCESSING PLANT UPGRADE PROJECT

COMMERCIAL UNIT – 2012

CAPACITY: 2.2 BLN. М3/YEAR

PRESSURE DROP: 12/10 АТМ

COMMERCIAL UNIT: IN OPERATION SINCE 2007

CAPACITY : 840 MLN. М3/YEAR

DEW POINT: -33°C ON HC; -25°C ON WATER


CAPACITY : 320 MLN. М3/YEAR



CAPACITY: 1.3 BLN. М3/YEAR


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Typical 3S-Separation Unit (Front View)

3S-Separator

Low Temperature Separator

Heat Exchanger

13

Typical 3S-Separation Unit (Back View)

Capacity: 100 MMCFD Pressure: 1100 psi Footprint: 25 х 33 ft Low Temperature Separator

3S-Separator Heat Exchanger

Basic 3S-Separation Unit for NGL Plants

Inlet gas is split into two flows: one is chilled at HE-1 Heat Exchanger, another one – at HE-2 Heat Exchanger. To ensure deep liquid extraction in 3S-separator, the inlet flow temperature is about (–70) – (– 90) oC. Cooled inlet gas after mixing goes to 3S-separator where it splits into two flows: treated gas, and rich gas-liquid flow (15-30% of inlet gas volume); this flow comes to Sep1 low-temperature separator. Gas flow from Sep1 separator mixes with treated gas from 3S-separator outlet; this flow comes to HE-1 where it heats up by cooling inlet flow and is now NGL plant sales gas containing mostly methane and small amount of ethane. Unstable liquid from Sep1 throttles down and goes to the HE-2, cooling part of inlet gas flow by partial evaporation of the liquid (i.e. HE-2 acts here as an evaporator). After HE-2 rich gas-liquid flow (ethanized condensate) is processed at the conventional LTC unit.

3SInlet gas

HE-2

Enriched mixture

Liquid

Gas

Gas

Sales gas

HE-1

JT

Блок 3S-сепарации

HE - Heat exchanger

Sep - Separator

JT

- Liquid hydrocarbons

- Feed gas

- Sales gas

- Gas-liquid mixture

- Joule Thomson valve

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Pipeline Gas Conditioning – Dew Point Control

For regular applications

Advantages: (in comparison to traditional LTS unit): • Provision of required

dew point at less pressure drop

• Higher NGL recovery at the same pressure drop

• Extended service

lifetime without need of compression

Separator

3SGas from wells

Gas to main pipeline

Hydrocarbon condensate and

water

Separator

3S-separation unit

- Feed gas

- Sales gas



For high inlet gas pressure applications

3S

Hydrocarbon condensate to

stabilization unit

Separator

Gas from wells

Heat exchanger

Gas to main pipeline

Separator

Hydrocarbon condensate to

stabilization unit

3S-separation unit with recuperative heat exchanger

- Water


- Feed gas

- Sales gas


Water for injection into reservoir

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Dew Point Control – Upgrade of Existing LTS* Facility

* LTS – Low Temperature Separation

An example of real plant upgrade project for increased gas volume

Doubled capacity of gas processing plant with minimun CAPEX

- Feed gas

- Sales gas



SAT, T

- Separator

- Heatexchanger

- Methanol

JT - Joule-Thomson valve

- Water

Condensate to Column

S-1Gas-liquid mixture

from wells

AT2

Methanol

S-2

Methanol and water mixture

JT

Gas to Processing Plant

S-3Condensate to Column

AT1/1

Sales Gas

Water

3S

T

AT1/2 AT1/3

V1 V2

3S-separation unit

Existing LTS unit

V - Valve

NGL Recovery: Problems & Solutions

Current Industry practice Low Temperature Condensation (LTC) is most popular solution for NGL recovery LTC ensures deep NGL recovery LTC units are expensive (CAPEX & OPEX)

ENGO Engineering provides engineering solutions for deep ethane and NGL recovery

with CAPEX saving up to 40% maintaining up to 98% level of recovery

There are two different solutions*

Solution A

Combination

of conventional LTC &

3S-separation

LTC+3S for lean gas

Solution B

Application

of new

scheme

LT3S for wet gas

* The solution choice depends on service conditions

Combination of conventional LTC and 3S-separation

LTC+3S

Inlet gas goes to 3S-separation unit from dehydration unit

70-90 % of inlet gas is processed to sales gas specs at 3S-separation unit

Gas/liquid mixture from 3S-unit (10-30% of inlet gas) is processed at LTC unit

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Solution “A” for NGL Recovery at Gas Plant

20-35% of CAPEX savings

Gas-liquid flow

Treated gas from 3S-separation unit

Inlet gas

Treated gas from LTC Unit

Sales gas

Sales products

Fractionating unit

LTC Unit

Compressor 23S-separation

unit

Compressor 1

Dehydration unit

Condensate

- Feed gas

- Sales gas



Lean Gas Solution

LT3S unit

unique solution which allows to eliminate

expensive LTC process for some gas compositions

8

Solution “B” for NGL Recovery at Gas Plant

Up to 40% of CAPEX savings

Treated gas

Sales products

Dehydration unit

Gas-liquid flow

Gas-liquid flow

Sales gas

Compressor 2

3S-separation unit

Compressor 1

- Feed gas

- Sales gas



Feed gas

Wet Gas Solution

4 4

55

15

41

41

0

20

40

60

80

100

120

LTC (Low TemperatureCondensation)

3S-Technology

Dehydration Separation Compression

CAPEX Comparison (LTC vs LT3S)

40% Cost

Savings

40% CAPEX savings can be achieved in project of new gas plant (GPP) construction by implementation of 3S-technology Solution B (LT3S). While the cost of inlet dehydration unit (4%) and outlet compressors (41%) is at the same level for both versions, the reduction in cost is in separation module (55% to 15% of total LTC CAPEX). Note: 40% cost savings might be achieved for specific working conditions: gas specs, pressure and etc.

CO2 Removal Solution A (CO2: 71%→15%)

Reduction of CO2 content in sales gas from 71% to 15%

Heat Exchangers

Unit

Column

P-2

Separator

Feed Gas

Outlet Gas

Outlet CO2

HE-2

JT-1

JT-2

HE-1

- Feed gas

- Sales gas



PHE

- Pump

- Heatexchanger

- Heat

JT - Joule-Thomson valve

Dehydration Unit

3S

- CO2-rich flow

P-1

CO2 Removal Solution B (CO2: 71%→3%)

Reduction of CO2 content in sales gas from 71% to 3%

Feed Gas

Outlet Gas

CO2

Compressor Unit 1

Compressor Unit 2

C-1

LNG 102

P

S

M

Dehydration Unit 1

LNG 101

LNG 100

3S

C-2

Sales gasbefore

compression

- Feed gas

- Sales gas



PLNG

- Pump

- Heatexchanger

- Separator

M - Mixer

- CO2-rich flow

C - Column

S

3S - SuperSonic Separator

Contacts

+ 7 (495) 540 4636

+ 7 (495) 540 4637

[email protected]

www.engo3S.com

http://www.engo3s.com/

engo general presentation

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