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Transcript of ENGO general presentation
New Solutions for Gas Processing
ENGO Engineering Ltd.
+ 7 (495) 540 4636
+ 7 (495) 540 4637
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
6
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
9
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
Capacity: 86000 nm3/h
Pinput/Poutput=86/54
Severo-Komsomol’skoe:.2012
Capacity: 42000 nm3/h
Pinput/Poutput=47/30
Muravlenkovskiy Gas Plant
Customer: Sibur
2004-2005
Capacity: 100000 nm3/h
Pinput/Poutput=30/17
Talimi (PetroChina)
2011
Capacity: 159000 nm3/h
Pinput/Poutput=108/70
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
COMMERCIAL UNIT: IN OPERATION SINCE 2014
CAPACITY : 320 MLN. М3/YEAR
DEW POINT: -30°C ON HC; -27°C ON WATER
COMMERCIAL UNIT: IN OPERATION SINCE 2011
CAPACITY: 1.3 BLN. М3/YEAR
DEW POINT: -40°C ON HC; -32°C ON WATER
12
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
15
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
- Liquid hydrocarbons
- Gas-liquid mixture
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
- Liquid hydrocarbons
- Feed gas
- Sales gas
- Gas-liquid mixture
Water for injection into reservoir
16
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
- Liquid hydrocarbons
- Gas-liquid mixture
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
8
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
- Liquid hydrocarbons
- Gas-liquid mixture
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
- Liquid hydrocarbons
- Gas-liquid mixture
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
- Liquid hydrocarbons
- Gas-liquid mixture
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
- Liquid hydrocarbons
- Gas-liquid mixture
PLNG
- Pump
- Heatexchanger
- Separator
M - Mixer
- CO2-rich flow
C - Column
S
3S - SuperSonic Separator
Contacts
+ 7 (495) 540 4636
+ 7 (495) 540 4637
www.engo3S.com