Offshore World

VOL.16 | ISSUE 1 | DECEMBER 2018-JANUARY 2019 | MUMBAI | US $ 10 | ` 150

OFFSHORE WORLD

INSIGHT INTO UPSTREAM & DOWNSTREAM HYDROCARBON INDUSTRY

DECEMBER 2018-JANUARY 2019 VOL. 16 ISSUE 1 MUMBAI US $ 10 ` 150

International Exhibition & Conference February 2020, Mumbai, India

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CONTENTS

NEWS FEATURE Trends to Watch for Oil, Gas, and Chemicals Sectors Worldwide in 2019

06

VOL. 16 | NO. 1 | DECEMBER 2018-JANUARY 2019 | MUMBAI | US $10 | ` 150 OFFSHORE WORLD R.NO. MAH ENG/ 2003/13269

FEATURE

Chairman Publisher & Printer Chief Executive Officer

Sealing the Unseen: Creating Efficiency through Emission Control

10

Unlock Critical Clues to Maximize Profitability in Refineries.

14

Savvy Separators: Introduction to Computational, Fluid Dynamics (CFD) for Separator Design

18

EDITORIAL

Editor Editorial Advisory Board Design Team Subscription Team Production Team

Maulik Jasubhai Shah Hemant K. Shetty Hemant K. Shetty Mittravinda Ranjan (mittra_ranjan@jasubhai.com) D P Mishra, H K Krishnamurthy, N G Ashar, Prof M C Dwivedi Arun Parab, Shankar Joshi Dilip Parab V Raj Misquitta (Head), Arun Madye

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Subscription Rate (per year): Indian - ` 810/-; Foreign - US$ 120 Price of this copy: ` 150/The Publishers and the Editors do not necessarily individually or collectively identify themselves with all the views expressed in this journal. All rights reserved. Reproduction in whole or in part is strictly prohibited without written permission from the Publishers.

Jasubhai Media Private Limited

Darshan Parekh, Technical Director, PILOT Gaskets And Engineers

Sandeep Mohan, Product Marketing, AspenTech Sunil Patil, Business Consulting Director, AspenTec h

Alex Read, Direc tor, Industr y Sec tor Management, Siemens PLM Software

Maximising the Opportunity with FTG Gravity Embracing Digital- Realizing Unfulfilled Potential in Oil and Gas Industry

28

Divjot Singh, Business Development Manager, Energy and Natural Resources, Cyient

Strategic Design Considerations for LNG Terminals

31

The IoT Effect: How Technology is Modernising Traditional Industries

36

Countering the Threat of Cyberattacks in Oil and Gas

39

Anand Narayanaswami, Direc tor, Business Development (Oil & Gas), Black & Veatch India Shawn D. Hoffart, Vice President, LNG Technology, Black & Veatch Dale Williams, Vice President, Projec t Direc tor, Black & Veatch

Martin Phillips, Product Manager, Fluenta

Katharina Rick, Partner and Managing Director, Boston Consulting Group - San Francisco Karthik Iyer, Principal, Boston Consulting Group - Boston

MARKETING INITIATIVE A Leader in Flow Metering Solutions Water Specialties Propeller Flow Meter

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NEWS

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PRODUCTS

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EVENTS DIARY

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BOOK SHELF

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Colm A. Murphy, Chief Geoscientist, Bell Geospace Limited ,

Offshore World | 4 | December 2018-January 2019

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NEWS FEATURES

Trends to Watch for Oil, Gas, and Chemicals Sectors Worldwide in 2019 The sectors enter the new year with increased volatility in prices and regulatory overhangs amid new business opportunities.

I

f there is one constant in energy markets, it is change, as the cost of inputs and prices shift and companies adapt. Separately, the chemicals sector has enjoyed positive growth and margins for the past few years, but signs of a slowdown could emerge. Although no one can know for certain what will happen in the next 12 months, it is useful to try to understand how the business environment might evolve.

a niche issue for energy companies. It is moving to the center of strategy and investment decisions. Major oil companies are investing in renewable energy; natural gas producers, shippers, and consumers are increasing their focus on mitigating methane emissions; and chemicals producers are ramping up their efforts to find solutions to plastic waste, through recycling and use of new materials and processes.

Across oil, natural gas, and chemicals, increasing US exports are helping to bolster activity, with all sectors showing continued growth in shipping to international markets. The United States has been a major producer, but now it is consolidating its position as a leading exporter of crude oil, refined products, and natural gas, thereby becoming a big influence on global market trends. Upstream capital expenditures have not yet recovered, as companies remain cautious, at least for the time being. Their focus seems to be more on demonstrating returns rather than investing for new growth.

Some countries are also stepping up efforts to reduce the environmental and carbon footprints of their energy and industrial sectors, with China, in particular, taking major steps to close down polluting factories and shift toward cleaner energy.

In the chemicals sector, at this stage of the capital cycle, major new capacity in base chemicals is expected to be commissioned in the near future; however, this could lead to lower margins by getting ahead of demand trends. Still, the sector could well avoid anything more than a mild downturn by phasing in ramp-ups in the new capacity, selling to the North American market, which is still quite robust, and taking advantage of improved US port facilities to export more efficiently to international markets. So, even with a possible slowing of emerging market growth and a shift to more reuse of plastics, the chemicals sector in the United States looks reasonably shielded from significant downside risk.

2019 Prospects: Sorting Through the Noise Moving further into 2019, what should we watch for? For example, what could happen when the impact from the tax stimulus begins to wane-and if interest rates continue to rise, dampening both investment and consumer demand? And what could happen if the current tariffs remain in place or are even expanded? In this case, a period of readjustment is possible as consumers face higher prices for traded goods and companies see higher costs of doing business due to tariffs on key materials such as steel, and also disrupted supply chains. The energy sector seems particularly vulnerable here, with its ongoing needs for specialized steel for pipelines, refineries, and chemical plants.

Regardless of near-term uncer tainty, the 2019 energy conversation is expected to increasingly include long-term issues. Sustainability is no longer www.oswindia.com

Moreover, technology is not standing still-the scope and pace of growth for low-carbon energy, autonomous and electric vehicles, energy efficiency, and distributed energy are becoming not just a topic for futurologists, but a focus of decision-making throughout the energy and chemicals value chains.

Looking further out in 2019, following are key trends likely to impact oil, gas, and chemicals this year:

• In a fluc tuating market, disciplined capital planning and productivity will be a differentiator. The previous downturn saw tremendous gains in cost containment, capital high- grading, and operating efficiency. Will this discipline be maintained? Learnings from the downturn should not be forgotten, and continuous improvement in technologies and operating practices will go on, as they always have.

Industry players could focus on two key lessons: adopting a disciplined approach to capital investment decisions and leveraging digital technologies to achieve higher capital productivity. • It’s not just about supply or markets-infrastructure matters.

Building and expanding pipelines, processing facilities, import and export terminals, storage facilities, and liquid natural gas (LNG) plants is a vital but often underappreciated part of the value chain. Crude oil price discounts have at times topped USD 20 in the Permian Basin and USD 50 in Western Canada because pipeline build-out lagged wellhead activity.

The phenomenal growth in natural gas production in the Marcellus Basin has often outstripped pipeline capacity, depressing prices for producers. The timing cycle for planning, permitting, and constructing infrastructure seems to be getting longer and more complex and is more often litigated by opposing groups. There are major infrastructure

Offshore World | 6 | December 2018-January 2019

VOL.14 | ISSUE 2 | FEBRUARY-MARCH 2017 | MUMBAI | US $ 10 | ` 150

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INSIGHT INTO UPSTREAM & DOWNSTREAM HYDROCARBON INDUSTRY

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FEATURES

projects moving forward, but delay can be costly. No one in oil, gas, or chemicals development can afford to ignore how this plays out, impacting price spreads and physical capacity to move products.

• Natural gas is here and not forgotten despite a dip in recent production. The abundance of moderately priced natural gas in Nor th America, like that from the Marcellus and Permian Basins, does not get as much attention as the oil sector. Yet it is enabling material long-term change in US and global energy markets. Natural gas continues to grow as a source of lower-carbon power generation here and abroad. The wave of new investment in petrochemical facilities would not be possible without the growing US natural gas and LNG supply. Moreover, the US is now a major player in global LNG markets, with two facilities in operation, at Sabine Pass and Cove Point, and four more due to star t up in 2019. This is expected to shape global prices, trade flows, and business models. Although uncer tainty exists, the recent decision to take a final investment decision on another major Nor th American LNG project (LNG Canada in Western Canada) is a strong vote of confidence in the viability of Nor th American gas supply.

• Sustainability is moving from the periphery to the core. Energy and chemicals companies are not newcomers to the sustainability agenda. They have been reporting and communicating on environmental footprints, impact mitigation, and sustainability for some years now.

However, increasing consumer awareness of environmental and climate impacts and societal expectations are driving more and more companies to embrace sustainability as a core part of business strategy, rather than an add-on activity. And it’s not just about plans and communications.

Major oil, gas, and chemicals companies are making increasingly sizable investments in companies and technologies to bring renewable, lowcarbon energy to consumers and to reduce their own environmental and carbon footprints. www.oswindia.com

• Digital technologies are increasingly intertwined with the entire oil, gas, and chemicals value chain. As alluded to in the 2018 Outlook, opportunities from digital technologies have the potential to unlock new value. More and more companies are looking hard at deployment of artificial intelligence, analytics, robotics, and blockchain to increase efficiency, productivity, reliability, and predictability of operations.

However, implementation at scale can be complex in the capital-intensive oil, gas, and chemicals environment, where the challenges of legacy equipment and the large number of suppliers should be addressed. Refining and petrochemicals have been in the vanguard of process automation for many years, but we are now seeing indicators that the other sectors are turning their attention to digital opportunities. Those that succeed could be well-equipped to thrive through business cycles and be responsive to customer and societal expectations.

What do these trends mean for the oil, gas, and chemicals business in 2019?

Companies should embrace many indicators, trends, drivers, and signals: Operational awareness and capital discipline tend to be core to success across the oil, gas, and chemicals value chains. It is expected to remain critical as the market shifts.

Addressing consumer, regulator y, and community concerns could also prove key to industry players. Meanwhile, investors will likely want to see sustained returns and capital discipline, not just volume growth. That may require companies to drive external dynamics deeper into the heart of decision-making at all levels.

Source: The Wall Street Journal

Offshore World | 8 | December 2018-January 2019

Offshore World is an all-encompassing magazine for the hydrocarbon and allied industries. A bi-monthly magazine, launched in December 2003, Offshore World disseminates authen c, cri cal and well-researched informa on on global hydrocarbon industry innova ons.

The magazine offers latest and strategic informa on on the upstream and downstream hydrocarbon industry.

The endeavour of Offshore World is to become a vehicle in making “Hydrocarbon Vision 2025” a reality in terms of technologies, markets and new direc ons, and to stand as a medium of reflec on of the achievements and aspira ons of Indian hydrocarbon industry.

Circula on: 25,370

OSW Target Segments

OSW Reader’s Profile

5% Hydrocarbon Explora on 10% Hydrocarbon Processing 20% Drilling and Equipment Manufacturers 10% Development and Produc on Companies 13% Transporta on and Logis cs Companies 12% Refining and Marke ng Companies 15% Plant, Machinery and Equipment Providers 10% Technology Solu on and Service Providers 5% Safety , Health and Environment

12%

13%

• CEOs & Senior Management of Oil Companies • Petroleum Engineers & Refineries Contractors • Project Managers • Refining & Pipeline Engineers • Corrosion Control Engineers • Opera ons Managers • Technical Managers • Safety Managers & Engineers • Purchase Managers • Marke ng Execu ves • Pollu on Control Specialists • R&D Personnel • Industry Consultants • Engineering & EPC Consultants • Indian & Overseas Industry • Associa ons • Training Ins tutes

15% 10% 30%

10% 5%

20% 5% 10% Hydrocarbon Exploration Hydrocarbon Processing Drilling and Equipment Manufacturers Development and Production Companies Transportation and Logistics Companies

Refining and Marketing Companies Plant, Machinery and Equipment Providers Technology Solution and Service Providers Safety, Health and Environment

OSW Region-wise Presence 53% Western Region [including Mumbai,Gujarat, Pune, etc] 23% Northern Region [including Delhi, UP, etc] 10% Southern Region [including Bangalore, Hyderabad, Chennai, Coimbatore, etc] 9% Eastern Region [including Kolkata, Assam, etc] 5% Interna onal [includes USA, MiddleEast, Russia, Brazil, Iran, China, Germany, Italy, France, etc]

FEATURES

Sealing the Unseen: Creating Efficiency through Emission Control

O

n 22 April 2016 (Ear th Day), 174 countries signed the Paris Agreement focusing on reducing G reenhouse Gas emissions across the world. This again increases the focus on regulator y standards for Fossil Fuel industries like Refineries and Thermal Power Stations which are anyways stringent. Refineries continue to be pushed towards remaining efficient, hazard free, and environmental friendly all against the global outcr y towards renewable source of energy. While emission standards are globally managed by the respective Pollution Control Boards, fur ther controlling Emissions means Refineries need to look at other avenues for complying with these regulations.

Fugitive Emission is defined as; any chemical or mixture of chemicals in any physical form which represents an unanticipated or spurious leaks from anywhere on an Industrial Site. It basically refers to all losses (usually volatile) materials from a process plant through evaporation, flaring, spills and unanticipated or spurious leaks. The focus of this ar ticle is primarily on Volatile Organic Compound (VOC). Majority of these volatile materials is not visible to the naked eye and to accurately measure appropriate thermal sensing devices need to be used to “sniff ”, detect and measure the leakage loss.

Usually these losses are calculated by the Process Engineer and taken into consideration during design however a significant amount of losses are caused by leaks in the sealing element of equipment such as  Agitators / Mixers  Compressors  Flanges  Pumps  Tank Lids  Valves In a study in Netherlands, 72% of Emissions from a single Refinery was attributed to leakage losses from Equipments, 18% from flaring, 5% from Combustion, 1% from storage and 4% from process emissions.

To put things in perspective, the United States of America estimates loss of material in excess of 300,000 Tonnes per year. Besides the obvious environmental effects this is a huge loss of valuable material and an important consideration in Plant inefficiency.

Sources of Fugitive Emissions The primar y purpose of a Seal is to contain a fluid and protect the immediate environment from contamination. Hence although losses per

EPA Report on Emission Standard in United States of America in 2008 Sources of VOC Fugitive Emissions: A significant por tion of Fugitive Emissions can be losses from unsealed sources like storage tanks, open- ended lines, pressure relief valves, vents, flares, blow-down systems, spills and evaporation from water treatment facilities. www.oswindia.com

piece of equipment might be deemed small there are usually so many items of equipment in a Refinery that the total loss via Fugitive Emission is very significant. For e.g. In a refinery for every pump there are usually 32 Valves, 135 Flanges, 1 Safety Valve and 1.5 Open Ended lines. Hence with so many potential sources, leaking losses are high and difficult to ascertain in value without proper help and planning.

LDAR (Leak Detection and Repair).

Leaking Losses are generally higher from dynamic equipment (compared to static equipment) and from older equipment. Furthermore the majority of actual emission will come from only a small fraction of sources (i.e. less than 1% of valves in gas/ vapour service can account for more than 70% of Fugitive Emission in a refinery.)

Offshore World | 10 | December 2018-January 2019

FEATURES

LDAR Program using infrared Cameras.

Leaking Losses from equipment can be significantly reduced by use of monitoring and maintenance programs such as LDAR (Leak Detection and Repair). Leaks are detected by monitoring equipment and repairs must be carried out if the leakage rate exceeds cer tain levels. LDAR consists of Volatile Organic Compound (VOC) detecting “sniffers” that help in detecting leaks from flanges, pumps and valves. A correctly implemented LDAR program could reduce Fugitive Emissions by 40% to 60% depending upon the frequency of inspections, the process control and the fluid used.

Leak Control Valves Studies have indicated that leaking valve stems are by far the single largest source (60%) of fugitive emissions in a Refinery. Majority of valves are sealed with Gland Packings or various combination of these solutions.

When selecting the correct Packing seal, considerations have to be given to the temperature, media and pressure to which the valve seal will be subjected, as well as the level of sealing performance required to comply with the Emission standard.

Packing Certification Packings can be tested to qualify them for various types of service, which also helps to assure fugitive emissions requirements are met. ISO 15848 (Parts 1 and 2), API 622, API 624 and VDI 2440, have been in use for evaluation and testing valves and/or stem packings to meet the relevant fugitive emission limits and requirements.

Seal Type

Description

Effectiveness

Die-formed flexible graphite with braided carbon yarn packing end-rings.

Most basic of today’s valve stem sealing solutions.

Flat die-formed rings come in various densities.

Temperature: 454° C (atmosphere) & 649°C (steam) Pressure: 4,000+ psig

Usually capable of 500 ppm leak performance.

This method has been providing adequate emission performance for over 30 years, but may not attain desired low level of emission.

Braided flexible graphite

Wire-reinforced flexible graphite yarn.

Same Temperature Same Pressure.

Capable of <500 ppm and <100 ppm performance. One size braid can be used to pack many different sized valves.

Engineered sets

Combination of die-formed Capable of <500 flexible graphite rings of various ppm and <100 ppm geometries and densities and performance. braided yarn or braided flexible graphite yarn packings.

Same Temperature Pressure: 10,000+ psig

Advanced technology spool packings

Allow on-site creation of ultra-low-emission packing sets using different types of braided flexible graphite in combination.

Offshore World | 11 | December 2018-January 2019

Qualification testing indicates average leakage of as low as 50 ppm.

www.oswindia.com

FEATURES

Different types of Gland Packings used in Valves.

Test Procedure

ISO 15848

API 622

Media

Helium or methane

Methane

Sensing method

Stem seal: Vacuum: Helium Flush: Helium or methane

Modified EPA Method 21 with fixed probe

90 psig

600 psig

Pressure

High temperature 200°C and 400°C

260°C

Thermal cycles

7

3

Actuation

≤ 2,500 cycles (on-off valves) ≤ 100,000 cycles (control valves)

1,500 cycles

Pass/fail

Class A: ≤ 10–6 cm3/s/m of stem diameter Class B: ≤ 10–4 cm3/s/m Class C: ≤ 10–2 cm3/s/m

Agreement of manufacturer and end user

Adjustments

Limited number and frequency

Limited

Testing of Valve Packing for Fugitive Emission (Image courtesy FSA) Refineries and petrochemical processors such as Chevron and Shell have established their own criteria for qualifying stem seals. These standards specify temperature, thermal c ycling, test media, number of ac tuations, allowable adjustments to maintain the seal during testing and emissions-measuring methods. The Shell specifications for fugitive emissions testing are covered in MESC SPE77-300 for prototype qualification testing and SPE77-312 for production testing.

Flanges Wh i l e i n d i v i d u a l f l a n g e s m i g ht n o t co nt ri b u te to a l a rg e l e a ki n g loss, each Refiner y utilizes so many flange joints that overall they contribute heavily to Emission loss. There can be enforcement of a combination of preventive measures to reduce these Emissions such as:  Regular Maintenance or Controlled Tightening of the Flange an  Selec ting the R ight selec tion of the Gasket.

the packing material independent of the valve. In addition to fugitive

In India, there is a still a common usage of Compressed Asbestos Fiber (CAF) G asketing material or Spiral Wound G askets with CAF Fi l l e r d u e to t h e i r e co n o m i ca l n at u re. C A F i s ex t re m e ly p o o r f o r Fu g i t i v e E m i s s i o n s a n d s e l e c t i n g a p p l i c a t i o n s p e c i f i c c e r t i f i e d

emissions, API 622 also assesses the corrosion effect the packing has on

nonAsbestos G asketing S olution can itself reduce Fugitive Emission

the valve stem material and tests for a number of physical attributes,

b y 4 0 0 % . Th e n o n A s b e s t o s G a s ke t i n g t e c h n o l o g y i n s o f t g a s ke t

including high-temperature oxidation resistance.

material combined with Flexible G raphite Sheets and K AMMProfile

The fundamental difference, bet ween ISO 15848-1 and API 622 is that the ISO standard qualifies the seal in the valve, while API tests

www.oswindia.com

Offshore World | 12 | December 2018-January 2019

FEATURES

ESA Best Available Technique Report on Leakage Rates

Comparison of Seal cost in the overall Cost Centre in a Refinery

e n s u re s t h a t A s b e s t o s b a s e d S e a l s a re b e i n g p h a s e d o u t d u e to ineffec tiveness w hen dealing with Emission loss.

Gasket Cer tification While selecting the right Gasket, ensuring compliance with cer tification is of primarily impor tance. For Gasketing material the primarily focus should be on TA-LUFT & VDI 2440 cer tification and approval.

changing from non-cer tified to correct cer tified solutions might seem expensive the ac tual unit cost is completely over whelmed by the savings in labour costs & plant downtime itself. Controlling Fugitive Emissions with the proper cer tified Sealing Solutions will mean greater compliance to LDAR and result in an overall Plant Efficienc y with increased production.

Note, TA-Luft only gives guidelines for compliance with permissible leakage limits and refers to other regulations for specific situations to measure and certify static and dynamic leakage values. Specific leakage rate limits for these seals are stated in VDI 2440. VDI 2440 utilizes Helium for testing with values of 10-4 mbar*l/(s*m) at temperatures < 250°C (482°F) and 10-2 mbar*l /(s*m) at temperatures > 250°C. These tests are able to determine the efficiency of the Gasket (Spiral or Soft) for fugitive Emission and can ensure ease of compliance with Gasket Material Selection.

The Cost Effective Wh i l e t h e l o s s o f va l u a b l e m ate r i a l i s a n o b v i o u s a d va nt a g e f o r controlling Fugitive Emissions there are hidden advantages too such a s M ate ri a l Co s t, La b o u r Co s t, Wa s te d En e rg y, P l a nt i n e f f i c i e n c y, Environment Cleanup or Environmental Fines.

In most cases, the cost of the actual sealing technology is negligible when compared to the investment made in the plant as a whole. While, Offshore World | 13 | December 2018-January 2019

Darshan Parekh Technical Director PILOT Gaskets And Engineers Email: Darshan.Parekh@pilotgaskets.com

www.oswindia.com

FEATURES

Un l ock C ritical C l u es t o Ma x i mi ze P ro f i t ab il it y i n Ref ineries.

I

n this industrial game of Cluedo to maximize profits, refiners need to

for process simulation and rigorous heat exchanger modeling, a seamless

leverage the best innovation can offer. This is crucial in the volatile

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FEATURES Fourth clue: Planning Model Update To manage their operations, refineries use planning tools to make better informed decisions. While traditional linear programming (LP) models are employed by these planning tools to find the most optimal plan, they are only accurate within a specific operating range of the refinery. Overtime, refineries move away from the operating range – for example, it can happen due to catalyst deactivation or other operational changes. This means that LP models become outdated, which reduces the effectiveness of the planning tools, which adds up to millions of dollars in lost profits.

The solution is to maintain the planning models, with the help of advanced process simulation software. This enables updates when the models are out of sync with the operating range of the refinery. Process simulation software is key to this solution, providing the predictive capability that comes with rigorous process analysis based on reaction kinetics, heat and mass balance. Today, leading solution providers have built-in integration Figure: To embark on this journey to maximize profits, refineries need to unlock critical clues to profitability.

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Offshore World | 16 | December 2018-January 2019

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Savvy Separators: Introduction to Computational Fluid Dynamics (CFD) for Separator Design If yo u wor k i n the f ie ld of proce s s a nd separation, chances are you have come across comput at i o nal f lu i d d y n a m i c s (C F D). CF D produce s a wide ra nge of emotions ranging from abjec t fear, of ten invol vin g f las hbacks to a l on g forgotte n unive rs it y c la s s a nd a dizz ying array of par tial - differential equations, to c u r i o s i t y and e ve n e nt h u s i as m. The purpos e of this a r ticl e is to al l ay those fears, answer some questions and he lp yo u b e com e a n e d uc ate d cons ume r of CF D.

CFD for separators Many would start by asking the “so what” question: Why and when should CFD be cared about? This question will be answered, followed by a brief introduction to CFD including the major multiphase models, answering some frequently asked questions (FAQs) and ending with a short case study example of CFD and automated design exploration being applied to a cyclone separator, all of which will be achieved without recourse to a single equation!

So why should CFD be part of the separator design?

In today’s “lower for longer” market, cost reduction is front and centre for all. CFD helps in all the phases of a project: from reducing the initial project costs (CAPEX) and operating costs (OPEX) to helping manage project extensions, such as tying in additional wells to an existing facility.

A subsea separator’s job is to separate gases and liquid prior to pumping.

Ensuring the separator meets its process requirements is important. The pump or compressor downstream will not perform as desired if there is carry-over or under (liquid in the gas stream and gas in the liquid stream). Should this occur, operations will have a very expensive problem to resolve.

In addition to meeting the minimum process requirements, there are other design considerations. There may be a need to reduce its weight to ease installation, understand how changes in upstream piping impact performance to provide a standardized design able to connect with many Subsea Processing Systems (SPS) configurations, minimize its size to reduce the amount of real estate used, minimize the pressure drop and the use and cost of internals.

Hand calculations, such as Stokes law, can be used to estimate the required residence time, but this involves assumptions about the flow (for example, www.oswindia.com

no short-circuiting or even distribution across the flow area).

Physical tests can be run, however these present their own challenges: cost and time, difficulty visualizing the complex multiphase flow, testing with process fluids and high pressures and temperatures introducing significant additional cost and safety concerns.

Using CFD, the flow patterns in upstream piping, inlet devices and within the separator can be predicted to ensure adequate residence time. Each separation mechanism can be studied such as estimating the tendency for liquid droplet re-entrainment due to high gas velocities and improving the performance of internals by increasing the uniformity of the flow to the demisters.

CFD achieves this with relative ease and speed, using actual process fluids, temperatures and pressures. After simulating the initial design, we can run “what-if ” design studies to see how the design can be improved. In short, successful use of CFD results in discovering better designs, faster and at a lower cost.

This is predicated on the assumption that the CFD study was conducted co r re c t l y, a n d t h e re f o re t h e re s u l t s c a n b e t r u s te d. M a ny o f t h e uncertainties of CFD can be systematically tested for (such as a mesh refinement study), or can be interrogated by an engineer who understands the relevant physics at hand (and not CFD). A common concern is that results must be “tuned” to be accurate. This is not necessarily the case as accuracy can be obtained through systematic testing, quantification and minimization of uncertainty and error, and by ensuring the problem is adequately posed and modelling assumptions are appropriate for the problem at hand.

The first step in interrogating a CFD solution is to use good engineering judgment. Does the flow field make sense, and if not, why? How does it compare with hand calculations, prior designs that have validation data and simpler analysis methods? In the early stages, CFD mistakes are often

Offshore World | 18 | December 2018-January 2019

FEATURES typos, so if it looks like the code solved a different problem to the one being investigated, there’s a good chance it did!

Next, it takes a deeper explanation to understand the major steps in the simulation process and the potential impact of these on the results.

CFD attempts to solve the Navier-Stokes equations which describe the behavior of fluids. Unfortunately, solving the Navier-Stokes equations is computationally intractable, so for all practical problems, the Reynolds Averaged Navier-Stokes (RANS) form is used. These suffer from the “closure problem” as they have more unknowns due to averaging which are resolved through the use of turbulence models. Models are also used to incorporate more advanced physics, such as multiphase flow dynamics.

Setting up a CFD study involves four steps: 1.

2.

3.

4.

Defining the domain of interest, geometr y, flow entr y and exit and boundary conditions (for example, velocity at the inlet) Discretizing or meshing the domain: Rather than solving for the fluid behavior (velocity, pressure etc.) at every point in space, we segment the volume using a mesh, then solve the equations only at the center of each cell in the mesh - think of a separator filled with Lego bricks. CFD will tell you what the velocity, pressure, temperature and so on, is at the center of each brick. For completeness, in time-varying problems, time is discretized by solving for time increments, such as every 0.1 seconds.

Selecting the physics to simulate, whether the flow is single phase or multiphase, thermal or isothermal.

The CFD program then iteratively solves the equations to convergence.

These steps also represent the four areas of uncer tainty and where attention should be focused.

If a 3D CAD model or drawings of the geometry exist and are available, defining the domain typically is not an issue. Defining the flow conditions at the inlet and outlet is more challenging. In separator simulations it is typical to prescribe a droplet size distribution at the inlet, which requires

knowing or estimating this. Typically, boundary condition information is available from other analysis methods – for example, from a 1D model of the system, from CFD by extending the domain of interest upstream to some point where there is less uncertainty or by hand calculations, for example, to estimate minimum droplet sizes. The engineer who performed the CFD study should be able to explain what conditions were used, what these mean physically and why they are appropriate.

Nex t, the domain (geometr y) needs to be discretized or meshed. This is an impor tant and potentially time - consuming par t of the analysis.

A good mesh begets good CFD. The mesh (number, size, and type of cells used) can influence the answer. As an example, if a CFD simulation is trying to simulate a vortex using one cell, the solver only has one point at which it calculates the velocity and pressure to represent the vortex. As the number of cells is increased, decreasing the size of each cell, the resolution and therefore accuracy of the representation of the vortex improves. A similar approach is used to ensure or minimize the influence of the mesh over the solution, the mesh is progressively refined (reducing cell size) until quantities of interest, such as pressure drop, stop changing. A short note on a well-established method for grid convergence studies can be found at1.

There are also different cell types: hexahedral (six sides), polyhedral (many sided, but typically soccer ball shaped with 12-14 sides) or tetrahedral (four sides).

Historically, tetrahedral meshes were often used, since building hexahedral meshes was difficult and time consuming, par ticularly for complex geometries. This is undesirable as tetrahedral cells have poor numerical properties; they artificially make the fluid behave as if it is more viscous.

As a consequence, many more tetrahedral cells are required to attain the same level of accuracy as when using hexahedral or polyhedral meshes.

Fortunately, meshing packages have improved significantly in the last decade, so it is now possible to build polyhedral or hexahedral meshes, even on complex geometries, without significant overhead.

Figure 1 : Different cell types: tetrahedral (blue), hexahedral (green), polyhedral (red) Offshore World | 19 | December 2018-January 2019

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FEATURES After building the mesh, the engineer must select the physics to consider.

One benefit of CFD is the ability to simplify problems to consider only the physics of interest, making it easier to interrogate and understand results and trends. This is also a double-edged sword as over simplifying can miss important effects. As with boundary condition selection, the engineer performing the analysis should be able to explain the models used, their physical meaning and appropriateness for the problem at hand.

In the separator world multiphase modeling is key. There are three main multiphase models used in CFD: Free-surface or Volume Of Fluid (VOF) Eulerian-Lagrangian Multiphase often shor tened to Lagrangian Multiphase or LMP Eulerian Multiphase (EMP) In the VOF approach, the interface between the phases is resolved with the mesh. As in Figure 2, if droplets of water fall under gravity through air, CFD can capture the motion of the droplet using the VOF model if there is adequate mesh resolution to capture the shape and motion of the droplet in the mesh.  



Consequently, this model is well suited for flows with a well-defined interface between the phases, such as stratified flow, where the mesh can be refined locally to capture the interface. A common application of VOF is to model the sea and its behavior around ships - there is a clear interface between the sea and the air.

VOF can be used to model flows other than stratified but the mesh needs to be refined to capture the multiphase effects at the interface between the phases, such as entrainment of fine droplets into the gas phase. However,

in an Eulerian framework with a fixed mesh and the flow motion relative to the mesh. The full name for LMP is Eulerian-Lagrangian multiphase, but the Eulerian is dropped for expediency.

For the dispersed phase, the trajectory of each particle or droplet is solved for using Newton’s second law of motion. The calculation of the droplet or particle motion is performed from the reference frame of the moving droplet, rather than the fixed mesh, which is known as a Lagrangian method. In order to reduce the computational cost and make it applicable to scenarios with a large number of droplets, each droplet represents an ensemble of droplets. Inputs to the motion calculation include submodels for the drag force and dispersion of droplets or particles due to turbulence. Additional sub-models can be introduced to include breakup and coalescence of droplets. The interaction between the phases can be either one- or two-way. One-way is where the motion of the droplets is influenced by the continuous phase but the continuous phase does not “see” the droplets; two-way is where both phases influence each other.

The one-way coupling is often applied.

This method is an efficient and accurate way to model droplet or particle flow but is less applicable when the volume fraction of droplets or particles is high. Opinions on the volume fraction cut-off vary but are usually in the 5-10 percent range, at which point the model accuracy and stability deteriorate. For particle flows, more advanced models can be used to address this, such as Discrete Element Method (DEM) or Multiphase Particle-in-cell (MP-PIC). In the separator world, LMP is often used to study the motion of droplets in the gas stream.

For Eulerian multiphase, the full RANS equations are solved for each phase.

Using the concept of “interpenetrating continua,” the continuous and dispersed phases interact through source terms for drag, lift, virtual mass and turbulent dispersion. This makes it an immensely flexible model, able to simultaneously handle any number of phases and any range of volume fractions. Sub-models can be included to account for additional physics such as breakup and coalescence of droplets or bubbles, or heat and mass transfer.

Figure 2 : Droplets modelled using VOF this increases the computational cost of the analysis. In the separation world, VOF is often used to evaluate the bulk flow properties of the vessel.

When the flow is dispersed, either Lagrangian Multiphase (LMP) or Eulerian Multiphase (EMP) is typically used.

In LMP, the continuous flow field is solved using the RANS CFD approach. In the example of droplets falling through air, the air is the continuous phase and the droplets are the dispersed phase. The continuous phase is solved www.oswindia.com

The disadvantages of EMP are that each set of RANS equations comes at a cost (studying many particle sizes or phases becomes computationally expensive) and the user needs to understand, and choose, appropriate sub-models and settings. The downside of EMP’s flexibility is that it can be applied to a wide range of multiphase flows, which results in multiple sub-models to be understood and applied.

For analysis of separators, EMP can be used to model the full vessel, but is particularly effective in mixing regions where volume fractions exceed the limitations of LMP and in tracking small droplets or bubbles with VOF is computationally expensive.

Having built the mesh, specified boundar y conditions and chosen appropriate modelling assumptions, the solver uses iterative techniques

Offshore World | 20 | December 2018-January 2019

FEATURES to successively improve the solution until “convergence” is attained .

Mathematically, convergence describes the limiting behaviour, particularly of a series towards its limit. In CFD, the series is the flow field (values for velocity, pressures etc.). The flow field reaches its limit when the values for velocity, pressure and so on, stop changing from iteration to iteration.

Convergence is often judged by monitoring residuals. Residuals measure the amount by which the discretized equations are not satisfied. A typical rule of thumb is that residual values should have dropped by three orders of magnitude.

If the residual values do not drop and the flow field continues to change, this may indicate that the steady-state assumption does not work due to inherent unstable phenomena like turbulence. Alternatively, it may indicate problems such as poor quality cells in the mesh or an ill-posed problem such as the location or values of boundary conditions.

Figure 3 : Geometry and flow visualization for baseline design the engineer to provide: Design objective(s): There can be more than one and these can be competing. In this case, the objective is to maximize the separation efficiency of the cyclone.



Case study: Design space exploration of a gas-solid cyclone separator to improve separation efficiency Having described the steps in setting up a CFD study and building confidence in the result, the following is an example of how CFD should be used to understand and improve the design and performance of a gas-solid cyclone separator.



Constraints to be applied: In this case, the pressure drop across the separator cannot exceed a certain value or else the design will be deemed infeasible.

The CFD simulations were run using STAR-CCM+®, a Siemens PLM software. Figure 3 shows the geometr y of the separator, streamlines through the device with an iso-surface showing areas of low pressure, volume rendering of pressure contours and a comparison between CFD using multiple methods and experimental data for mean axial velocity at two locations in the cyclone. The purpose of these simulations was model verification, which is why multiple methods were used for the same case.

The baseline geometry for the design study is from an European Research Communit y On Flow, Turbulence and Combustion (ERCOFTAC) paper where the geometry and experimental data - Laser Doppler Velocimetry (LDV) - of the mean velocity profiles across the cyclone are available.

Having validated the base model, CFD allows us to explore design alternatives quickly and easily. It can also be used in conjunction with tools that will automate the simulation process and efficiently explore the design space. In this case, the HEEDS multidisciplinary design exploration software from Siemens PLM, in conjunction with STAR-CCM+, was used.

For the design space exploration study, a constant gas velocity of 25 m/s was applied at the inlet. Sand particles with a diameter of 1.2 µm were introduced at the inlet, such that they accounted for one percent of the volume fraction of the flow. LMP with a one-way coupling to the continuous phase was used, along with the Reynolds Stress Turbulence model (RSM).

The automation and design space exploration tool HEEDS uses algorithms to predict the next exploration point in the design space. HEEDS requires

Figure 4 : Baseline cyclone geometry 



Different load cases to be evaluated, for example if the separation performance is different at different particle loadings.

Design variables: Their extents and sensible increments are to be defined. In this case, we vary the radius of the cyclone, the length of the constriction and parallel wall sections.

Many different approaches have been developed to help explore the design space efficiently. These are often referred to as optimization algorithms and include among others Design of Experiments (DOE), genetic algorithm,

Offshore World | 21 | December 2018-January 2019

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FEATURES

Figure 6 : Correlation plot efficiency and pressure drop (correlation of 0.74 and 0.71 respectively).

Summary To the non-specialist engineer, CFD can be initially daunting, particularly in more advanced areas such as multiphase flow and separation. While detailed knowledge of sub-models will remain with the specialist, non-specialist engineers can critique CFD results by evaluating whether the physical meaning of the results be explained and asking about the modeling decisions taken and their anticipated influence on the results and quantities of interest. By introducing the main multiphase models used, this article aims to help in this process.

Figure 5 : Geometry of improved design, velocity magnitude along a plane section through the center of the cyclone and design study history showing the progressive improvement in separation efficiency downhill simplex and particle swarm. Optimization is often a misnomer since for most industrial applications no single optimal solution or design exists.

However, these techniques can be highly effective in identifying better designs.

An impediment to the application of these methods is their multitude: Users must understand which method to use for any given scenario. HEEDS uses a hybrid and adaptive algorithm called SHERPA, which will switch between different exploration methods (DOE, genetic algorithm and so on) depending on the information it has about the analysis such as the number of variables and time and resources available.

The benefit of using these methods is that they find better designs in less iteration than an engineer on their own or other optimization methods.

CFD compliments other analysis methods (analytical or experimental).

Its successful application can have a significant, positive financial impact on projects: by reducing the cost of design, improving and validating equipment per formance and mitigating problems before they occur.

Linking CFD with automated design space exploration tools can further the understanding and improvement of separator designs.

References 1. http://journaltool.asme.org/templates/jfenumaccuracy.pdf 2. https://www.nafems.org/join/resources/cfdconvergence/Page0/ 3. http://www.ercoftac.org/

The correlation plot shows the relationship and degree of correlation between two variables, such as the radius of the cyclone and the cyclone separation efficiency. The numbers on the top right-hand side show the correlation between the two variables represented in the square (1.0 indicates perfect correlation).

The correlation plot helps the engineer to interrogate large amounts of data (100-plus designs), and to understand quickly what influences the design. In this case, the cyclone radius has a significant impact on its www.oswindia.com

Offshore World | 22 | December 2018-January 2019

Alex Read Direc tor, Industr y Sec tor Management Siemens PLM Soft ware Email: alex.read@siemens.com

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capability to detect, delineate and map prospects with incredible

wells drilled were FTG anomalies.

resolution. These technology advances have been largely in seismic and drilling capabilities and benefit enormously with increased computing power through design, implementation and processing know-how. However, many of these also involve increased expense leading to challenging decisions for exploration managers in the current climate. Do we continue to spend, do we reduce capability, and do we reduce the work program? How does one promote new acreage using these new technologies in a low price environment? How does one streamline prospects with limited funds to optimise their holdings?

These are just a handful of questions facing such managers.

Many companies have looked to alternative technologies to help mitigate

The Full Tensor and 3D Gravity field FTG comprises 12 gravity measuring devices arranged in 6 pairs with 2 pairs on each of three separate spinning discs. Each spinning disc ensures the field is measured in all directions of the 3D field and all at the same time on any single survey. The technology detects density contrasts lying both directly beneath and in between survey lines, a feat unmatched by any other gravity measuring technology. The combined output measures the rate of change of the gravity field as detected in sub-surface geology at an unprecedented resolution. The stark difference

against this imposition and to maintain their work programs. Airborne

with conventional gravity measuring devices is that unwanted signal, in

geophysics has seen increased uptake in recent times and rapid advances

the form of platform contributions to the signal, is cancelled out. This

have been made, with increased resolution now the norm. Airborne

facilitates measurement of the gravity effect of subtle density contrasts

magnetics, airborne EM and airborne gravity gradiometry have all made a

sourced by subtle geological changes in the shallow section.

break through with their ability to detect, delineate and map prospectively The different outputs are transformed into a Gravity Gradient Tensor

at an unprecedented scale in recent years.

field that allows direct detection of complex geological body shapes as Airborne gravity gradiometry is arguably the most successful of these new

they present themselves in a typical geological setting. Such features

technologies. Gravity gradiometry maps the gravity field as recorded by

include closed fault blocks, anticlinal closures, salt bodies, carbonate

sub-surface geology and presents an order of magnitude greater resolving

mounds from many intra-basinal settings, but also include mapping

power over its conventional counterpart, Gravity.

primar y basin forming trends and regional tec tonic settings from strike -slip, normal and reverse faults. This combined high accuracy,

Airborne Full Tensor Gradiometer (FTG) goes one step further in mapping

high resolution output facilitates mapping of the 3D subsurface geology

the 3D Gravity field and has witnessed a rapid uptake by the Oil & Gas

on any given sur vey.

www.oswindia.com

Offshore World | 24 | December 2018-January 2019

FEATURES F TG d a t a i s a c q u i re d f ro m b o t h s e a - g o i n g ve s s e l s a n d f i xe d w i n g

FTG for the ages

a i r c r a f t . A i r b o r n e a c q u i s i t i o n i s c h a l l e n g i n g, b u t s u r v e y w o r k co n d u c te d o n s t a b l e, s l ow m ov i n g p l at f o rm s s u c h a s a B a s l e r Tu r b o

The key focus for FTG since then has been in delineating intra-basinal

a i rc r a f t ( Fi g u re 1 ) o f f e r i m m e n s e v a l u e. Th e l o n g w i n g s p a n a n d

structuring in many play model environments: from Carbonates and

h i g h e n d u r a n c e c a p a b i l i t y e n s u re s a c q u i s i t i o n o f h i g h l y a c c u r a te, h i g h re s o l u t i o n d a t a i n a t i m e l y f a s h i o n . B e l l G e o s p a c e o p e r a te s t h re e s u c h a i rc r a f t wo r l d w i d e, o f t e n c i t i n g t h e a i rc r a f t ’s u n i q u e o f f e r i n g a s a ke y d r i ve r i n t h e i r a b i l i t y t o d e l i ve r h i g h q u a l i t y F TG d a t a o ve r t h e ye a r s.

Thrust-Fold belts in SE Asia and India, to back-arc and fore-arc basins in the Americas, southern Europe, and the Middle East, to Rift Basins in Europe and Australia to fault mapping in unconventionals exploration in the US and Australia. FTG’s unique ability to simultaneously measure all components of the gravity field means it is best suited to mapping the 3D shape of geological structures generating density contrasts.

Tullow Oil’s success in 2009 with FTG is remarkable. The target geological structures were a series of tilted faulted blocks. Cored by basement rock and overlain by lacustrine sediments and shales, their density contrast is ideal for detection. Conventional gravity data acquired initially established the concept model, but as much of the acreage is over difficult to reach parts, an airborne solution was sought. The 26 out of 27 successful wells drilled by 2009 are underpinned by positive FTG anomalies (Fig2) with the only duster being associated with a negative anomaly.

FTG’s success in Uganda lead to extensive survey work elsewhere along the East African Rift from Ethiopia to Kenya, from Malawi to Mozambique and

Figure 1: Basler Turbo 67 aircraft used for acquisition of FTG data by Bell Geospace Early successes with FTG

activity is still ongoing with recent surveys just completed in Tanzania and Zambia. The uptake since 2009 has been immense, with Petronas, Repsol, Sasol, and BG, to name a few, adopting the technology in their exploration workflows. Delineation of key rifted segments and their complex structuring

Some of the first FTG projects were offshore in the Gulf of Mexico, Nor th

are confirmed by sparse seismic coverage where available and used to steer

Sea, and Nor way’s Barents Sea in the 1990’s and early 2000’s where salt

planning of new seismic acquisition, both 2D and 3D. The value is efficient

models were defined for seismic workflows.

use of exploration budget at a time when costs are everything.

FTG helped depict accurate depth and body shapes of complex salt bodies, including overhang development and connectivity with deeper mother salt. Density-depth models proved to be of immense use for early stage PSDM workflows that served to advance seismic imaging exercises.

Sub-basalt imaging with FTG was also achieved offshore in the Faroe Islands at the turn of the centur y. Largescale basaltic lava flows are characterised by a laterally homogenous density expression making them blind to gravity sur veying methodologies. The impact is that high resolution gravity sur veys image sub-basalt geology accurately. High resolution FTG established depth to tops of the key Mesozoic fault blocks underpinning trapped hydrocarbon occurrences and were confirmed by drilling on Statoil’s Brugdan prospect in 2006.

Figure 2: FTG mapping hydrocarbon bearing structures in the Albertine Basin, Uganda.

Image reproduced from joint Africa Oil and Tullow Oil presentation at UBS Global Oil & Gas Conference, 2012.

Offshore World | 25 | December 2018-January 2019

www.oswindia.com

FEATURES Petronas in Malaysia committed in 2012 to FTG survey work over large areas both onshore and offshore Peninsular Malaysia, Sarawak and Sabah. 4 years and 162,000 sq kms of FTG data later, the data coverage represents the largest single holding of FTG by any operator. The diverse and complex array of anomaly patterns is testament to the technologiesâ&#x20AC;&#x2122; ability to resolve some of the complex geological exploration challenges in these parts.

The Sarawak Basin is well established as an oil producer with many producing fields from the carbonate platform since the 1970â&#x20AC;&#x2122;s. The current focus is to now image sub-carbonate to identify and delineate new plays. The carbonate properties and body shapes are a challenge for conventional seismic workflows leading to long processing times. FTG does image sub-carbonate, identifying basins and migratory pathways that feed the productive reservoirs within the carbonate itself. Figure 3

Figure 3: Depth Map from FTG data in Malaysia â&#x20AC;&#x201C; cold colours map basins lying directly beneath the Luconia Carbonate Platform

shows a depth to top Pre-Cycle Basement generated from FTG data over

conventional rift basin with the development of a series of half-grabens.

the Luconia platform offshore Sarawak. The FTG Depth Imaging workflow

Plays have been successfully drilled with two oil accumulations from well

establishes a variable depth to the dominant metasedimentary basement

NNG-1 (Jabber et al, 2015). The deeper of the two pools resides at Top

and predicts the presence of pre-Carbonate basins reaching 4km depths

Basement defined by a tilted fault block structure. Corresponding FTG

(cold colours). The additional benefit is direct mapping of key structural

data facilitates direct mapping of the structure (Figure 4) away from that

lineaments interpreted as faults predicting both transfer and normal fault

depicted in the seismic. The negative anomaly pattern coincides perfectly

activity. These serve as migratory pathways for generated hydrocarbons

with the basinal troughs where the source rocks reside.

from depth into the overlying Carbonate hosted reservoirs.

Th r u s t a n d f o l d - b e l t s e t t i n g s a re i d e a l h u nt i n g g ro u n d s f o r F TG West of Luconia in what is known as the Half-Grabens of the Tatau

applications. The nor th-western shores and onshore Sabah, Malaysia,

region, the geology changes from dominant carbonate platform to more

has received much interest with regional 2D seismic and geological map

Figure 4: FTG response over a successfully drilled half-graben structure offshore Malaysia (seismic from Jabber, 2015) www.oswindia.com

Offshore World | 26 | December 2018-January 2019

FEATURES data being the primar y technologies used to delineate thrust faults,

FTG signal is transformed to a conventional gravity field and combined

anticlines, and synclines. FTG data acquired in 2015 confirms the

with legacy gravity data to produce a Full Spectrum Gravity product

published interpretations of Cullen (2010) with positive anomalies

making it ideal for resource and play modelling concepts. Innovative

t ra c ki n g t h e t h ru s t / re ve r s e f a u l t p at te r n s a n d co l d co l o u r s t h e

analysis methodologies of the Tensor data facilitate detailed 3D imaging

known synclines. Figure 5 shows the one - on- one correlation with

and accurate depic tion of target struc tures. Combined with depth

corresponding fault picks made from 2D seismic data. The availability

information accessed from seismic and other technologies, the data is

of the FTG data now ensures confident mapping of the synclineâ&#x20AC;&#x2122;s extent

transformed into a 3D density model. Results from joint work with industry

previously only predicted from the seismic.

leaders demonstrate the true value of FTG and represents a future direction for FTG technology.

The recent shale - gas exploration successes across the US required innovative solutions for traditional geophysics, with the source and

Driving exploration with FTG

reservoir being the same target, presenting a challenge for cost effective detection. FTGâ&#x20AC;&#x2122;s usage in such projects has been to map fault patterns

FTG fast-tracks exploration through its unique ability to not only locate basins and basement settings but also directly identify and delineate intra-basinal structuring leading to informed play model mapping. The technology is proving to be of immense value in driving exploration activity in both mature and frontier areas alike. The recent work offshore Malaysia identifies sub-carbonate basins and new play concepts leading to improved exploration in this long established producing region. Continued work along the East Africa Rift identifies new plays along Lake Malawi and detailed mapping of pertinent strike slip fault patterns impacting shale-gas exploration in the Utica of Ohio, USA. Collective decision making by the industryâ&#x20AC;&#x2122;s leading players, both NOCs

Figure 5: FTG response over a previously mapped thrust fault and syncline. Grey lines locate composite seismic section with white fault lines coinciding with picks shown on the seismic. Seismic line and geological interpretation on FTG data reproduced from Cullen (2010). both on the regional and prospec t scale to assist with drill planning exercises. Mapping such struc tures is critical to minimise risk due to potential leakage from source and potential contamination of ground

and IOCs is now leading to ambitious plans to roll out FTG on largescale basin wide surveys that will build the new base maps that will serve to re-define known opportunities but equally important help open up new basins and play concepts.

This cost-effective exploration technology maximises opportunity helping maintain exploration strategies in the current low price environment.

water supplied. FTG data was acquired in SE Ohio over the Utica play in 2014 for this purpose and identifies the regional strike -slip fault pattern impac ting the distribution of targeted shale horizons.

Continued development FTG development continues at pace. 3D depth imaging workflows that involve seamless combination of FTG signal with conventional gravity, ability to image geology in between survey lines, extraction of geological signal and prediction of a density field are now proven and widely revered that direct usage in challenging seismic imaging projects is truly viable.

Offshore World | 27 | December 2018-January 2019

Colm A. Murphy Chief Geoscientist B ell Geospace Limited, Edinburgh, UK Email: cmurphy@bellgeo.com www.oswindia.com

FEATURES

Embracing Digital- Realizing Unfulfilled Potential in Oil and Gas Industry Not l o n g a g o, the c ruc ia l rule of the game was foc used on l arge produc tion. The rul es then s hi f te d - to b e t te r m a rg i ns be c a us e of a s ignif ic a nt imbal ance in demand and suppl y, geo -pol itic al decisi o ns, and low c ru d e p r i ce s. In the c urre nt e conomy, e fficiencies in operations is the name of the game and t he i ndu s t r y s e e m s to h ave f ixe d the ir e ye s on one major frontier: digitization

D

igitization, which can be described as collecting, monitoring,

from smar ter exploration, easy capturing of data, robust reser voir

and analyzing huge amount of data, can bring a dawn of new

modelling applications, safer operations, and interoperabilit y of data

operational efficiencies using sensors, increased computational

across exploration ac tivities. This helps not only in reducing costs

power, automation, remote configuration and optimization, control

and better utilization of labor, but also, if done well, in transforming

systems, and even ar tificial intelligence. Analyzing big data is not new

the planning process with predic tive analytics. This provides E&P

for an industr y that has relied on data for decades to understand the

companies with a better shot at anticipating and responding to ever-

potential of reser voirs that hold billions and trillions cubic feet of oil

changing market scenarios.

and gas. Yet the industr y, par ticularly upstream, has been struggling to become “more digital.” Many companies are now giving their digital strategies a new lease of life to curb the menace of a rather painful downturn and position themselves for nex t growth cycle.

Although the potential benefits of automation in the entire upstream value chain is evident, some of the biggest and impactful oppor tunities exist in production operations. With oil and gas companies looking to deeper seas for resources, any downtime will become costlier than it was at any time before. Automation may create several benefits for operator to that end: asset utilization and integrit y and increased field recover y. There is another oppor tunit y lying ahead, not just for oil and gas producers, but also for drilling operators and oilfield ser vices companies.

Payment Process An often neglected area for exploration and production companies is the ability to speed up the ever daunting and slow process of payments in this industry. Some E&P companies are trying auto-executable contracts and quick payments transfer by using blockchain technology that removes the requirement of a mediator to validate transactions. By accelerating the industry’s slow payments process, technology can free up cash for exploration, lower a company’s operating expenses, and contribute to higher margins per barrel.

Drilling Contractors Asset Strategy Since the downturn, many drilling operators had either cancelled new orders or refurbished their old rigs to continue working with aging

Digitization is not just about much needed efficiencies; it is also about

assets. Many companies may have to reassess their portfolios, and make sure that they capable of supporting increased activity and new drilling environments. Most will need to redefine their fleets to match those opportunities—and likely will have to expedite retirement of some older rigs. Operators and drillers should collaborate in developing scenarios for balancing the supply and demand of rigs over the long term to reduce

enabling E&P companies to develop power ful capabilities to benefit

the risk of fleet investments.

Digital approach of major upstream stakeholders Exploration and Production companies Smart Exploration

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Offshore World | 28 | December 2018-January 2019

FEATURES

Figure 1 : Impact of digitization on Upstream Value chain Technology

assistant can provide a technician clear instructions in the field when a

All three upstream stakeholders, operators, drilling contractors, and

safety valve stops functioning. The idea of virtual assistant may seem

oilfield services providers have to work together to transform the entire

futuristic, but already a major oilfield services company is trying an AI

end-to-end technology solution by introducing more automated drilling,

based virtual assistant providing assistance to its field engineers for its

data-centric approach, and condition-based maintenance. This requires

logging operations.

acceptance from all the stakeholders about challenges and opportunities new technology brings to the sector.

Key themes of digitization across oil and gas Industry

Oilfield Services

Predictive Analytics and Asset Management

Connected Oilfield

Asset management has been a much talked about topic in the industry,

Th e co n n e c te d o i l f i e l d i s a b o u t a n i nte g rate d a p p ro a c h to w a rd s

but it is only now that oil and gas companies are warming up to utilize

operations: using IT to change processes for better decision making,

its full potential. Coupling asset management with predictive analytics

remotely access, monitor and control equipment, and to move more

has ushered in a new age of out of the box solution to reduce costs of

func tions and personnel onshore. This approach ensures that not

operating an asset. Asset maintenance, in many industries, is moving

only risks associated with business, health, safety, and environment

from a time bound inspection towards a risk based assessment of assets.

are reduced but also the objectives of going digital are achieved. A

This ensures minimum downtime and reduced costs and occurrences of

connec ted oilfield works on a vir tual environment where effec tive

emergency repairs.

communication and collaboration among experts can occur, regardless of where the exper ts are physically located or to which organizations they

Artificial Reality and Wearables

belong. For example, a basic ability to remotely recalibrate a pressure

Many te chnol ogy commentators have a l rea dy written a lot about

gauge makes sure that relevant data can be shared and incorporated in

applications of ar tificial realit y / vir tual realit y in our daily lives.

the decision-making process quickly, avoiding delays and saving safety

Imagine this: a field engineer is wearing a smart glass that shows him 3D

risk, time, and money. A lot of visualization tools are being developed

schematics, guidelines, and video instructions to repair a critical failure

that will aid in ensuring seamless integration of data, thus making

in an offshore gas turbine that powers the operations of a huge process

interpretation of data easier and availability of data transparent.

platform. Or a wearable that guides you to the nearest evacuation points in case of emergency. This kind of over-the-shoulder coaching will not only

Use of Virtual Assistants

reduce downtimes drastically, it will also reduce HSE risks and expedite

With the advent of chatbots, it is not difficult to imagine that a virtual

on-the-job training for new employees.

Offshore World | 29 | December 2018-January 2019

www.oswindia.com

FEATURES •

Look for significant trends that dominate the industry with focus on identified areas of the value chain, and take a decision to either innovate or adopt tested technologies and processes.

•

Define the links between a company’s most critical decisions and digital applications, and show how these applications improve efficiencies of existing processes.

•

Most companies falter by considering digital strategies as a one-time approach. Evaluate the investment to digitize identified processes and activities and support with a multi-year budget and roadmap.

•

Acce p t a n d a s s e s s t h e g a p b e t we e n c u r re n t p e r s o n n e l capabilities and capabilities required to implement new technologies,

Figure 2 : Oil and Gas Industry is slowly bracing automation

Internet of Things, Data analytics, and Process Efficiencies Big data has been talk of the town for the past five years, and rightly so. Rich data that had been lying unused for decades suddenly became useful and helped companies in shaping their strategies to iron out efficiencies in their operations.

All this has been possible by ensuring that companies collect right data using sensors that feed continuous data to the cloud. As we look to expand scope and

and plan an upgrade of existing talent or leverage a partner.

Way Forward The journeys of this digital transformation will not always be rosy, and they will differ depending on maturity on the digital ladder, ambitions, and financial provisions. Digital leadership is not always the best strategy, and it can be expensive. Although at a time when companies are reducing their capex extensively year on year, this strategy might look

applications of Internet of Things, oil and gas companies are finding newer ways

odd. However, with the ever-decreasing cost of digital transformation,

to collect more data and devise strategies to improve efficiencies further. It is

rapidly improving tools, and potential reduction in operating costs, this

an unavoidable truth that many oil and gas companies either have made a new

area should have enough bandwidth in terms of focus and budget. It is

CXO position of Chief Data Officer or are in the process of hiring one.

no coincidence that all the major themes on digital transformation lead on to some degree of automation, and it is anybody’s guess that the

Overcoming Human Resource Crisis using Artificial Intelligence

industry is indeed headed towards automation. While en route on this

and Machine Learning

digital transformation, it should not be forgotten that any strategy should aim to create a competitive advantage over the next three to five years.

O i l a n d g a s i n d u s t r y i s u n d e rg o i n g o n e o f t h e b i g g e s t “f o rc e d ”

All of these propositions should include initiatives that offer short-term

transformations at this time: Human Capital management. There is

gains and ensure that the companies develop long-term competitive

widespread unknown of losing many experienced professionals, as many

advantage to reap the benefits of digitization.

tenured employees are going to retire in next 3-4 years or have switched to other professions to weather the downturn. Many players across the industr y are tr ying to digitize the knowledge and experience these professionals possess. As the age of AI and high computational power dawns on us, we can use these tools to create an intelligent database of all these experiences. A database that not only grows, but also learns.

Strategy to Plan for the Digital Future •

Identify key areas of value chain that has the highest impact on financial and operating parameters, and treat them as opportunities to improve delivery through digital approach.

www.oswindia.com

Offshore World | 30 | December 2018-January 2019

Divjot Singh Business D evelopment Manager Energy and Natural Resources Cyient

T

h e I n d i a n g a s m a r ke t i s p ro j e c te d to b e o n e o f t h e f a s te s t

annum (MMTPA) plant at Jafrabad in G ujarat. The new FSRU will be

growing in the world during the nex t t wo decades. To help

moored to a fixed jett y.

f a c i l i t ate t h i s t h e I n d i a n g ove r n m e nt a i m s to s i g n i f i ca nt ly

increase liquefied natural gas (LNG) impor t capacit y by 2022. This

Although marine and storage requirements need to be considered

ar ticle gives an over view of key considerations during the development

in the selec tion of the terminal site, perhaps more impor tant are

and design phases of an LNG impor t terminal projec t.

the potential safet y and environmental aspec ts of a par ticular site.

Many jurisdic tions have quite detailed requirements for siting an

M a n y s u b t l e f a c to r s e n t e r i n t o l i q u e f i e d n a t u r a l g a s ( L N G ) i m p o r t

LNG facilit y. These requirements can include regulations covering

te rm i n a l p ro j e c t d e c i s i o n s. B l a c k & Ve atc h h a s b e e n i nvo lve d i n t h e

ever ything from fish habitat, air emissions and surrounding proper ties

d e ve l o p m e n t a n d d e s i g n o f m o re t h a n 2 5 L N G i m p o r t te r m i n a l s.

to the potential impac t of an incident.

Th e c o m p a n y h a s p e r f o r m e d wo r k r a n g i n g f ro m d e s k to p s t u d i e s, to d e s i g n a n d p e r m i t t i n g, t o f u l l e n g i n e e r i n g, p ro c u re m e n t a n d

One of the most impor tant criterion to consider for siting is how the

construction (EPC) responsibilit y for terminals in India, the

plant will get the necessar y seawater into and out of the facilit y. The

A m e r i c a s, Eu ro p e a n d Af r i c a .

required frequenc y and size of LNG carriers can also heavily influence

To design a safe, efficient and cost- effec tive terminal, a number of

site selec tion. Environmental impac ts arising from shipping and the

fac tors require careful attention: • Terminal siting and environmental fac tors.

• Storage tank size and requirements.

• Marine considerations.

• Vaporization technology selec tion.

• Oppor tunities for integration with adjacent industrial facilities.

It is impor tant to note that these factors are not entirely independent of one another. For example, both LNG storage capacit y and marine design are influenced by ship size, coastal and shipping constraints and terminal throughput.

Additionally, LNG impor t terminals can be land-based or floating. In some cases, the floating LNG application was selec ted to reduce the overall projec t schedule time to star tup, while in other situations this application was used to mitigate siting constraints.

I n J u l y 2 0 1 7 Sw a n L N G Pr i v ate L i m i te d a w a rd e d B l a c k & Ve atc h t h e E P C c o n t r a c t t o d e l i v e r I n d i a’s f i r s t f l o a t i n g s t o r a g e a n d re g a s i f i c a t i o n u n i t ( F S R U ) , f o r t h e 5 m i l l i o n m e t r i c t o n n e s p e r Offshore World | 31 | December 2018-January 2019

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FEATURES

Strategic Design Considerations for LNG Terminals

FEATURES

type of LNG vaporization often determine the viability of a prospective

carriers that will discharge cargos at the terminal. In addition, factors

site and the designs of the facilit y.

such as weather delays and tide changes must be considered when determining the amount of storage required bet ween ship arrivals.

Although originally developed for use in the United States, many

Although larger tanks have been construc ted, a t ypical industr y tank

jurisdictions around the world use National Fire Protection Association

size is 150,000 cubic meters (m3) to 180,000 m3. When one considers

(NFPA) 59A, Standard for the Produc tion, Storage, and Handling of

that carriers of over 260,000 m3 are in the fleet, it is easy to see that

Liquefied Natural Gas (LNG), as a reference when establishing LNG

multiple tanks are often required for a terminal.

terminals. In addition to these widely recognized standards, numerous local codes are t ypically followed for the design and operation of

In addition to ship size, another impor tant design parameter is how

LNG terminals.

often ships will arrive and the expec ted range of LNG send- out rates.

Because weather plays an impor tant par t in the ability of a ship to dock

Fac tors such as the impac t on the local communit y and adjacent

and load/unload LNG, a clear understanding and study of expec ted

industrial areas often dic tate the suitabilit y of a potential terminal

weather and marine conditions is a must. The general prac tice in

site. Analyses of potential vapor dispersion and thermal radiation

the industr y is that before an LNG carrier is connec ted at the ber th

impac ts have become much more detailed than just a few years ago.

and begins discharging its cargo, the terminal must have sufficient

Numerical techniques such as computational fluid dynamics (CFD)

capacit y available to store the entire cargo.

m o d e l i n g a n d t h e u s e o f a p p ro ve d c a l c u l a t i o n p ro t o c o l s ( a l o n g with risk assessment studies) are par t of modern terminal siting

An o t h e r f a c to r a f f e c t i n g s to ra g e co s t i s t h e t y p e o f t a n k d e s i gn .

considerations.

Generally, large LNG tanks are construc ted according to one of three design t ypes: single, double or full containment. The choice of tank

B ecause storage requirements are often the largest single par t of the

design is not only based on tank erec tion cost but also on safet y and

terminal capital investment, they are often the focus of potential cost

location. Generally, single containment tanks have a single metal

savings. However, storage cost is largely driven by the size of the LNG

wall capable of storing cr yogenic LNG and a secondar y containment

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Offshore World | 32 | December 2018-January 2019

FEATURES

provided by an ear then berm. Full containment tanks are constructed

(both initial and maintenance) and por t restric tions. In addition,

with a metal LNG storage container surrounded by a full concrete

p a ra m e te r s s u c h a s b at hy m e t r y, s p a ce f o r s h i p m a n e u ve ri n g, t u g

struc ture that provides the secondar y containment.

o p e rat i o n , wate r d e p t h , t i d e va ri at i o n s a n d wave a c t i o n a re ke y.

It is critical, early in the design process, that these parameters be

D o u b l e co nt a i n m e nt t a n k s s u b s t i t u te a co n c re te o u te r s t r u c t u re

researched and the projec t approach and basis be documented. It

for the ear then berm for secondar y liquid containment, but do not

is also impor tant that a dialog be established with the local por t

provide secondar y containment for evolved LNG vapor. Few double

authorit y and pilots association.

c o n t a i n m e n t t a n k s a re b e i n g c o n s t r u c t e d b e c a u s e t h e y h a ve n o significant advantage over other designs and have higher relative

Once ship size, ber thing requirements and mooring requirements are

costs. B ecause of the bermed containment area, single containment

known, the mooring struc ture, loading arms, piping and equipment

tanks require more plot area than full containment tanks. However,

must be considered. In addition, the safet y protocols that will be

full containment tanks have higher costs and longer erection schedules

obser ved during LNG transfers must be documented as par t of the

than single containment tanks, which must be considered in the overall

design basis. Employing a marine contractor with both LNG and local

designs and economics of the facilit y.

experience is vital.

Terminal designers must consider marine fac tors such as expec ted

Many different vaporization technologies are in use in LNG impor t

s h i p s i ze ( l e n g t h , d ra f t, e tc. ) , c h a n n e l t ra f f i c, d re d g i n g re q u i re d

terminals around the globe. These can be categorized into a few

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FEATURES

classifications depending on the medium used to warm the LNG:

location is too high, corrosion can be an issue. Seawater to freshwater

â&#x20AC;˘ Open rack vaporizers--water falling over LNG tubes.

exchange can be utilized, but this process adds cost. There are still

â&#x20AC;˘ S u b m e rg e d co m b u s t i o n va p o r i ze r s - - L N G h e ate d i n a l i q u i d b at h ,

locations where the use of open rack vaporizers is a good choice, but these facilities are less common than they once were.

t ypically fueled by natural gas. â&#x20AC;˘ Heat exchange vaporizers--via shell and tube exchange and an ex ternal fluid heatin g loop.

At one time, most LNG facilities around the world used open rack v a p o r i z a t i o n . Th i s s t y l e o f v a p o r i ze r u s e s s e a w a t e r d i s t r i b u t e d over heated finned tubes to vaporize the LNG. Operating expenses for open rack vaporizers include elec tricit y for pumping water and a ny n e e d e d f i l te ri n g o r t re at i n g o f t h e i n l e t s e awate r. Th i s t y p e

Submerged combustion vaporizers burn fuel to generate the heat needed to vaporize the LNG. In locations where the use of seawater is restricted, these vaporizers are common. For example, many of the older LNG facilities in Europe and Nor th America use this style of vaporizer.

Although these vaporizers are efficient, they still consume fuel and have air emissions. In addition, the combustion air blowers that are

of vaporizer has become less common in new designs because of

par t of these systems consume electrical power. The operating cost

considerations surrounding the use of large volumes of seawater and

for a modest-sized LNG impor t terminal using submerged combustion

potential environmental impac ts to sea life from cooling the water

vaporizers can run into the tens of millions of U.S. dollars per year.

used in vaporization. In addition, if the distance to the open sea is

Because they are relatively compac t and can be put into operation

considerable, expensive seawater pumping and piping systems can

quickly, submerged combustion vaporizers are at least a par t of the

be required. And, if the mineral content of the water in the terminal

vaporization system in many new LNG impor t terminals.

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Offshore World | 34 | December 2018-January 2019

FEATURES Heat exchange vaporizers are used in an attempt to overcome the

• The Peñuelas facilit y for EcoElec trica in Puer to R ico. B lack & Veatch

limitations of other vaporizer types. Generally, these units are large

was one of many contrac tors involved in the design and construc tion

heat exchangers that conduct energy from either warm water or warm

of this facilit y. The power plant has the abilit y to generate elec tricit y

air to the LNG to be vaporized. Because of the potential for freezing, the

using liquefied petroleum gas (LPG), LNG and other fuels. It is heat

design of these exchangers is specialized. For example, in the case of a

integrated with the LNG impor t facilit y and ver y flexible. It is one of

water heated shell and tube exchanger, the water side of the exchanger

the ver y few facilities with a U.S. permit to use double containment

could freeze and burst if a tube ruptures. Often, the water has added

LNG storage.

glycol to minimize the impact of the ver y cold LNG, but even that can

• The successful construc tion of the Energia Costa A zul terminal in

freeze. In warmer climates, the water used to vaporize the LNG is heated

Baja California, Mexico. This facilit y includes t wo 160,000 m3 full

using the ambient air, but in more ex treme climates, some other heat

containment LNG storage tanks and seawater open rack vaporizers

source is often required. Air heated units may have ice buildup from the

and is completely self-sufficient in terms of power generation and

moisture in the air. Often, multiple parallel units must be installed to

freshwater produc tion.

allow some exchangers to thaw while others are in ser vice. The main advantage of heat exchange vaporizers is that the source of heat is essentially “free” and that little energy is needed for operation. However, these vaporizers are not without their environmental impacts. The use of toxic glycols and discharge of condensed water can affect a design.

As can be seen from the discussion of LNG vaporizers, some heat source is often needed to vaporize the LNG. Therefore, LNG impor t terminals are often candidates for integration with adjoining facilities. Black & Veatch has developed designs for integration with power plants,

• Co m p l e t e d e s i g n p a c k a g e s f o r U. S . F e d e r a l E n e r g y R e g u l a t o r y Commission (FERC) facilities: detailed design packages for p e r m i t t i n g f o r ove r 1 0 N o r t h Am e r i ca n L N G i m p o r t te r m i n a l s f o r submissions to FERC, including Cheniere Sabine Pa ss te rm i n a l, th e Sempra Cameron facilit y at Hackberr y, Louisiana, and the O ccidental Chemical Corporat ion (Ox yChem) LNG terminal in I n g le si d e, Texa s.

For t he Ox yChem LNG terminal, B lack & Veatch inte grate d th e L NG terminal into t he ex ist ing facilit y for t he supply o f a ll h e at f o r th e plant vaporizat ion.

chemical plants and other industrial par tners. For example, in a power plant, a large por tion of the energy used to generate steam is ultimately rejected in a steam condenser. The power produced is a function of the outlet pressure and temperature of the steam turbine condenser.

This condenser is limited by the temperature of the cooling system. By exchanging heat with an LNG impor t terminal, a much cooler condenser outlet can be achieved and more power can be produced for a given

Anand Narayanaswami, Direc tor, Business D evelopment (Oil & Gas), Black & Veatch India

amount of fuel. Because many LNG impor t terminals are co-located with power plants, this type of integration can be a significant boost to project economics, both in reduced energy consumed by the LNG terminal and increased energy produced by the power plant. In fact, LNG vaporization “cold” can be used in a number of ways, including cooling for chemical plants, mineral processing and refrigerated storage.

Shawn D. Hoffar t, Vice President, LNG Technology, Black & Veatch

Black & Veatch References • In 2015 IOCL awarded a Black & Veatch led consor tium the contrac t for a new LNG receiving terminal at Ennore. Black & Veatch is leading the EPC and commissioning work on a turnkey basis. The terminal will be the first- of-its-kind on India’s east coast, with a send- out capacity

Dale Williams, Vice President, Projec t Direc tor, Black & Veatch

of five million tonnes.

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The IoT Effect: How Technology is Modernising Traditional Industries Th e Inte r n e t o f Things (IoT ) re fe rs to physic al devices embedded w ith el ec tronics, sof t ware, s e ns o r s and n e t wo r k con ne c tiv it y whic h e na ble objec ts to col l ec t and exchange data. To date consumer ap p li c at i o ns h ave i n c l u d e d the a c tive monitoring of wel l being through wearabl e hear t monitors and sma r t co nne c te d a p p l i a n ce s i n the hom e. Howe ve r, the re al benefit is l ikel y to be fel t by industries w here remote mo ni to r i ng a n d m e a s u re me nt c a n va s tly re duce cos t and improve efficiencies. Traditional industries, such as o i l and g a s, a re n ow p ois e d to a dopt m ore IoT a nd cl oud technol ogies, using a net work of devices and s o f t ware to m o n i tor a n d me a s ure a n a lmos t unlimited number of tasks.

A breakdown in communication For the Oil & Gas Industr y to effec tively supply its consumers around t h e w o r l d, i t i s e s s e n t i a l t h a t o p e r a t i o n s r u n s m o o t h l y. S h o u l d e q u i p m e nt b re a kd o w n o r a s s e t s f a i l, t h e e co n o m i c i m p a c t o f a n unplanned shutdown can be severe. For example, in 2014 Indonesia experienced a reduc tion in its crude oil sales, largely caused by the 122 unplanned shutdowns from the operator BPMigas, which created 6,860 bpd in lost produc tion.

For oil and gas companies, upholding regular maintenance and calibration schedules can be difficult and expensive. However, cloud technology and the availability of internet connectivity has driven significant progress in remote asset management – enabling assets to be remotely and securely monitored and managed offsite.

Cloud technology and internet everywhere Cloud technology and the availabilit y of internet connec tivit y have d r i v e n s i g n i f i c a n t c h a n g e i n re m o t e a s s e t m a n a g e m e n t. C l o u d infrastructure enables the constant monitoring and storage of data on remote ser vers any where in the world in real time via IoT. Monitoring equipment installed on local assets transmits information to software

Providing they are connected to the internet, businesses can access CEMS data and analyse it using a variety of devices. With internet connectivity available almost anywhere, businesses can access the real-time data feeds of remote assets from multiple sites anywhere in the world. It is not necessary to store and run the software on a machine on-site, which reduces cost and removes the need to have on-site staff. Additionally, the data is stored securely on multiple remote servers with back up and is not dependent on the health and reliability of an on-site machine.

R e m o te a c t i o n c a n b e t a ke n to u p d ate s o f t wa re, s h u t d o w n f a i l i n g o r f a u l t y s y s te m s, a n d i f t h e re i s a d a n g e r o f e x p l o s i o n , e x t r a c t o n - s i te p e r s o n n e l i m m e d i a te l y. E m p l o ye e s wo r k i n g f o r o f f s h o re o i l a n d g a s o p e r a t i o n s we re f o u n d to b e s e ve n t i m e s m o re l i ke l y t o d i e o n t h e j o b t h a n t h e a v e r a g e U. S . w o r ke r, a c c o rd i n g t o a s t u d y re l e a s e d b y t h e Ce n t re s f o r D i s e a s e Co n t ro l a n d P re ve n t i o n (C D C ) . Th e C D C t ra c ke d f at a l i t i e s f ro m 2 0 0 3 to 2 0 1 0 a n d f o u n d t h at 1 2 8 p e o p l e h a d d i e d w h i l e wo r k i n g a t o f f s h o re o p e r a t i o n s. Wi t h advances in remote monitoring technologies, fewer engineers w i l l n e e d to wo r k i n h o s t i l e o r d a n g e ro u s e n v i ro n m e n t s s u c h a s offshore rig locations.

CBM

that is stored on central ser vers, rather than physically on an oil and

Condition based maintenance (CBM) – enabled by remote monitoring

gas site. When real-time data is fed into software such as a continuous emission monitoring system (CEMS), organisations can collec t record and repor t data remotely –this method has several benefits.

- reduces the risk of major equipment failure by identifying potential

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problems before they come to fruition. CBM involves continuously monitoring the condition of an asset – including its components – so

Offshore World | 36 | December 2018-January 2019

FEATURES

maintenance can be carried out as soon as there is an indication that a device or its components may not be func tioning effec tively. CBM compares ac tual per formance with average per formance, or with a pre -programmed range. When device parameters move beyond what

Historically, these checks were the responsibility of personnel. People would need to confirm whether assets were working or not. Not only does remote measurement and polling of these assets reduce cost – it helps eliminate human risk.

is acceptable, it signals the need for maintenance.

In late 2015 dozens of oil workers were killed in a fire aboard a rig in the In addition to component failure, CBM data feeds can aler t management if soft ware needs to be changed or updated, if sensors

Caspian Sea. This was caused by a gas pipeline that was damaged in high

n e e d c l e a n i n g b e c a u s e o f i ce o r d i r t, o r w h e n e q u i p m e nt n e e d s

the impact of extreme weather on oil rigs and implement procedures to

calibrating for accurac y.

reduce the risk of a similar incident. Had the owners of the rig been more aware of the likelihood of such an incident happening, the site could have been evacuated earlier.

Data can be collected from on-site equipment and streamed to a central location for analysis via the internet. This helps to reduce cost and minimise the requirement for on-site engineers, but can also improve the efficiency and accuracy of emissions reporting.

winds. By recording critical data to the cloud, companies can understand

A greener, more connected future

Oil and gas operations can be dangerous. Although rare, there is a risk of on-site explosions. The Hydrocarbon Releases (HCRs) that cause explosions like these are, in simple terms, leaks. It is inevitable that

Outside of running an efficient and safe operation, emissions reduction is another key consideration for the Oil & Gas Industry. An International Energy Agency (IEA) report, “CO2 Emissions from Fuel Combustion Highlights,” estimated that the energy sector is responsible for more than 40% of global carbon dioxide (CO2) emissions. Gas flaring is one of the primary contributors to industrial emissions. Based on satellite data, it is estimated

leaks will happen during operations, and while significant effor ts

more than 150 billion cubic metres (or 5.3 trillion cubic feet) of natural gas is

have been made to reduce these, innovations in remote monitoring

released into the atmosphere each year through natural gas flaring and cold

technology can drastically reduce risk. Regular repor ts of asset well-

flaring (venting) operations. While gas is often flared for safety reasons, a

being and asset monitoring will aler t operators when an asset is malfunc tioning – or is about to do so – reducing the risk of a leak.

large proportion is still flared as the main method of disposal - for facilities

Safety first

that do not have the infrastructure to capture, transport and monetise it.

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FEATURES Real-time data can also be used to create a competitive advantage.

Data retrieved from different sites can be compared to more effectively manage processes â&#x20AC;&#x201C; site to site, country to country, or process to process â&#x20AC;&#x201C; enabling continuous improvement over time. Best practice can be taken from top performing sites and implemented across the entire business operation.

Conclusion

In November 2015, the COP21 climate change conference in Paris saw a number of oil and gas companies sign a pledge to reduce routine gas flaring to zero by the year 2030. This means an increased focus on emissions being recorded and shared with regulators. The Oil & Gas Industry has come a long way in its recognition and reduction of emissions.

However, under increased regulatory scrutiny, it is crucial that the flaring of natural resources is strictly limited and only takes place when absolutely necessary. It is connected technologies that are now helping to measure and manage these processes more effectively.

In the last five years the industr y has made significant moves to re d u c e e m i s s i o n s , i m p l e m e n t i n g I oT a n d c l o u d t e c h n o l o g i e s t o accurately collec t emissions information and provide insight that will streamline emissions heav y processes.

Measuring emissions

Flaring may be largely used for the safe disposal of excess natural gas, but the burning process is damaging. Measuring flare gas is important for reducing environmental impact but is one of the most challenging types of gas flow measurement. Connected technologies are helping to refine maintenance procedures, deliver more accurate emissions information and provide insightful data to advance on-site emissions strategies through the cloud. IoT connectivity enables organisations to accurately report pollutants from gas flaring and manage gas flaring processes more effectively in offshore locations. While traditional industries have been slow to realise the potential in technology, oil and gas companies are finally considering its transformational role.

It is important for the Oil & Gas Industry to sustain production and ensure its internal processes continue to operate efficiently and safely. One way to do this is through regular asset monitoring, maintenance and servicing.

IoT innovation has transformed how these processes can be completed.

Connected technologies can greatly reduce the risk of accident or injury in oil and gas operations, improve emissions monitoring, and provide insightful data to advance on-site operations through cloud technologies and internet everywhere.

Historically, recording and sharing emissions data would have involved recording the volume of gas flared locally and sharing data on a periodic basis. However, connected measurement technology means that now this information can be monitored and measured in real time through secure hosting in the cloud. By using cloud technology to record gas flaring, companies can build a better picture of trends over time and use this insight to drive emissions strategies.

For example, on an oil rig where flaring only happens after cer tain maintenance procedures, real-time data can provide insight to more effectively manage the flaring process â&#x20AC;&#x201C; reducing the amount of wasted gas. Over an extended period of time organisations may begin to see patterns emerging that enable them to more effectively predict which rigs will flare more gas than others. www.oswindia.com

Offshore World | 38 | December 2018-January 2019

Mar tin Phillips Produc t Manager Fluenta

Cybersecurity is particularly high in oil & gas industry compared to most other industries due to its global nature of oil & gas production and distribution. While transactions in the oil & gas arena are broad in scope that includes sensitive information on such diverse topics as possible well sites and end-user consumption which are vulnerable to cyber attacks; furthermore, the industry faces threats that are activist (including attacks carried out by environmental groups), rather than purely commercial, in nature. These cybersecurity threats could have severe effects not just on the industry but also on the environment, public health and safety, and even national security. The article describes various modes of cyberattacks in the oil & gas industry and the focus areas that the industry needs to look at in protecting themselves, their shareholders, and their customers adequately.

A

cross industries, companies have been intensifying their focus on cybersecurity. This is a direct consequence of the expanding role that digitisation is playing in their business and operating models, and the demonstrated potential for significant damage resulting from a successful cyberattack. Indeed, CIO magazine’s “2015 State of the CIO” survey revealed that chief information officers now spend roughly a third of their time on cybersecurity-related issues and consider cybersecurity one of their top-four priorities. 1 In our work, we are seeing keen interest in cybersecurity among other senior executives, including board members and CEOs. Concern about cybersecurity is particularly high at oil and gas companies, which face a far wider spectrum of threats—threats that are potentially more severe—than do companies in most other industries. 2 Transactions in the oil and gas arena are broad in scope—the life cycle of a transaction can include sensitive information on such diverse topics as possible well sites and enduser consumption—so the companies are vulnerable at many different points.

These companies are also subject to relatively large-scale threats, given the global nature of oil and gas production and distribution.

Furthermore, the industry faces threats that are activist (including attacks carried out by environmental groups), rather than purely commercial, in nature. These include threats that, if successful, could have severe effects not just on the industry but also on the environment, public health and safety, and even national security. 3 Recognising the severity of the situation, many oil and gas companies have taken significant measures to address their vulnerability. Have they done enough?

In a recent survey of a number of industry players, The Boston Consulting Group found, for example, that none of the companies had undergone a comprehensive audit (spanning corporate, upstream, midstream, and downstream operations) of its value chain.

Many Points of Vulnerability—But Where to Focus?

The scope of activities within the oil and gas industry’s value chain creates many potential points of entry for attack (See Exhibit 1). It also leaves the industry prone to multiple types of attacks. These include attacks on the industry’s physical infrastructure (such as cutting fiber-optic cables), the disabling of critical systems (through denial-of-service attacks, for instance), and the theft or corruption of information or the prevention of its

dissemination. Given the industry’s relatively high degree of automation and interconnectedness, the effects of such attacks could be highly damaging to these companies. These effects can include the loss of equipment (for example, failed pressure-valve systems), the loss of competitive advantage (through the loss of, for instance, confidentiality of production data or possible drilling sites), and even the loss of life.

In light of the industry’s multiple points of vulnerability and the potentially catastrophic consequences of a successful attack, it is important to determine where these companies should focus their cybersecurity efforts. An examination of the critical vulnerabilities of analogous industries may be instructive. A 2014 report issued by the US Department of Homeland Security’s Industrial Control Systems Cyber Emergency Response Team (ICS-CERT) identified a wide range of information security weaknesses evident across what the US government classifies as “critical infrastructure sectors.” 4 The report found that vulnerabilities in three specific realms were most prevalent across these sectors: boundary protection, information flow enforcement, and remote-access control.

Vulnerabilities in these areas can open doors to a range of attacks. Inadequate boundary protection, which can make it difficult to detect nefarious activity, can create avenues that allow outside parties to interface with systems and devices that directly support a company’s control processes. Mobile and multimedia devices, including smartphones, have become integral parts of what were formerly considered secure boundaries and offer new potential points of attack. Insufficient control of information flows can allow attackers to establish unsanctioned and damaging communications using a company’s channels, ports, and services. Weak control over remote access can create many entry points for unauthorised interfacing with a company’s control-system devices and critical components.

For oil and gas companies, where is the exposure to these three vulnerabilities greatest? To make that determination, we examined these companies’ value chains, using the number of systems and integration points as a proxy for exposure. Upstream data emerged as the most vulnerable. We then looked at a simple upstream drilling infrastructure for help in identifying and understanding where the security gaps in upstream operations were largest.

(See Exhibit 2) As the exhibit shows, most security efforts related to upstream drilling infrastructure are focused on the security of physical assets rather than the security of information. Often, for example, data is transmitted from old or unsecured equipment and without standard protocols or security precautions.

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FEATURES

Countering the Threat of Cyberattacks in Oil and Gas

FEATURES

As a result, many companies’ upstream assets have glaringly unaddressed vulnerabilities to cybersecurity attacks.

Until recently, the industry considered the traditional upstream systems in oil and gas to be relatively safe because they were, in most cases, isolated. But the industry’s growing use of connected industrial systems and networking technology—coupled with the ever-increasing need for real-time data and analytics—has introduced new risks. These include asymmetrical threats against which the upstream segment is relatively unprotected compared with the industry’s corporate and retail segments.

The upstream segment’s heavy reliance on oil-field-services companies and use of nonstandard equipment and potentially insecure technologies further increases the number of potential entry points for attack and elevates the risk the segment faces.

To fortify the security of their upstream operations and related information, companies must add a broad and effective security layer on top of their existing upstream defenses. Such a layer, which would allow the companies to proactively detect intrusions and other forms of attack, should consist of such elements as firewalls, network-monitoring equipment, and network use rules that can secure systems and also enable the infrastructure to detect intrusions and associated patterns. These elements will help ensure that all

information flows are authorised and that there are adequate authentication procedures in place to ensure that unauthorised parties cannot gain access to critical systems. This will help oil and gas companies manage cybersecurity risk across the upstream supply chain.

Shoring up Defences Realising the need for taking concerted action against cybersecurity threats across the entire business, oil and gas companies have taken collective steps to mitigate risks. These include the formation of information-sharing bodies, such as the Oil and Natural Gas Information Sharing and Analysis Center, an industry effort launched in the US in 2014 to provide information and guidance to US energy companies.

Oil and gas companies also stand to benefit from government measures aimed at bolstering their defenses. Many governments, including those of the US, the EU, Russia, and Saudi Arabia, have developed national cybersecurity policies or frameworks, focusing specific attention on critical infrastructure. ICS-CERT, for example, was created to monitor and respond to cyber-security incidents across critical domestic sectors, performing security assessments of and making recommendations related to industrial systems. The NATO Cooperative Cyber Defence Centre of Excellence seeks to enhance cybersecurity-related capabilities, cooperation, and information sharing among NATO member states, as well as a number of NATO partner organisations from around the world that focus on the issue, including the Euro-Atlantic Partnership Council and the Istanbul Cooperation Initiative.

These various bodies and efforts notwithstanding, individual oil and gas companies need to take primar y responsibility for their cybersecurity themselves. We recommend a risk-based approach centered on three steps: • Develop an understanding of the precise risk to the company’s assets and the effort and resources necessary to mitigate them: With that understanding, the company should prioritise its security efforts. Cybersecurity risk varies considerably, depending on a host of variables, including the type of asset, its position in the value chain, and its physical location. The consequences of an attack can also vary materially. An effective detection and response scheme will aim at addressing the largest threats first.

• Build and sustain a multilayered defense system: Such a system should protect against various attack vectors. Management of this is highly complex and requires organisational alignment, the right technologies,

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Offshore World | 40 | December 2018-January 2019

FEATURES clear processes, and strict organisational discipline. Threats to hardware infrastructure, for example, are different from threats to software, and it is imperative that oil and gas companies have resources that address both. 5 Companies must therefore identify vendors whose equipment has been field-tested against a barrage of attacks. The companies must also be able to pinpoint sources of attack and mobilise the right sets of tools and resources in response. The ability to continually monitor all infrastructure, prioritising threats and defenses, requires both agility and an organisational readiness to redirect technology and people to areas where they are needed most. This system and approach is considerably different from the traditional top-down, linear work-order process that is still employed in many segments of the oil and gas industry.

• Manage cybersecurity risk on a consistent basis: The company must be well prepared to detect and respond to various types of attack across the value chain. Reaching this state will demand that the company’s processes, systems, and people are continually adapting to the changing landscape of cybersecurity risk. It will also demand active leadership at the executive level, which is essential for ensuring that the organisation is capable of responding to asymmetric attacks quickly and with agility.

These efforts should be supplemented by a number of midlevel priorities, including the following: • Understand critical assets and the role of information relative to those assets at the institutional level and ensure that the right skills and personnel are available to safeguard vital information.

• Conduct frequent audits and assessments of points at which critical information is being transmitted in order to identify and secure vulnerabilities.

• Engage in data-shaping activities that boost the company’s ability to recognise exceptions to normal data flow and transmissions, exceptions that could indicate attempted attacks from external parties.

• Recognise and act on the knowledge that, in many cases, people are a company’s weakest links. Most attackers target systems that have been made vulnerable through user apathy, inattentiveness, and ignorance.

An organisation may have the very best technologies and processes, but if its people are unable or unwilling to comply with established security measures, the effectiveness of its defenses is greatly diminished. Adequate training and awareness is therefore critical for ensuring that the entire organisation (including IT staff, R&D professionals, and business and other users)—not just portions of it—is well braced to help resist and weather cybersecurity threats. Active promotion of best practices, such as the use of encrypted storage devices and strong passwords, can go a long way toward creating a robust people defense.

• Ensure that the company’s partners—for example, vendors and oil-fieldservices companies—adhere to the company’s organisational-security guidelines, including the use of companyapproved hardware and software. Employees of these organisations should also have an adequate understanding of the basic principles of information security and management.

Lower-priority—but still important—measures include ensuring that there is sufficient redundancy in critical systems to enable uninterrupted operations in the event of denial-of-service attacks and providing a “kill switch” to disable connectivity in order to stop an intruder (with sufficient backup in place to

allow processes to stop safely). Companies’ orientation toward these and all security-related requirements should be comprehensive in nature and focused on continually managing risk, meeting or exceeding industry standards, and limiting negative impact on the business and customers.

The increasing technological complexity of today’s oil and gas industry— driven by, for example, the industry’s spiraling deployment of data mining and analytics technologies, sensor and networking technologies, industrial systems, and systems integration technologies—is rendering it increasingly vulnerable to cyberattack. To protect themselves, their shareholders, and their customers adequately, industry players must make cybersecurity a highest priority and an ongoing consideration at the executive level.

References: 1. “2015 State of the CIO,” January 5, 2015, http://www.cio.com/article/2862760/ cio-role/2015-state-of-the-cio.html#slide9, and Carla Rudder, “These 4 responsibilities just jumped to the top of CIOs’ to-do lists,” The Enterprisers Project, November 18, 2015, https://enterprisersproject.com/article/2015/11/these-4-responsibilities-just-jumpedtop-cios-do-list.

2. Indeed, as oil and gas companies deal with the severe oil-price decline, cybersecurity is among the few areas that they will likely continue to fund.

3. Information on the oil reserves of various nationstates, for example, is extremely sensitive, and its illicit distribution could have global geopolitical ramifications. Hence, many governments, as well as businesses, are making concerted efforts to address cybersecurity.

See, for example, NATO Cooperative Cyber Defence Centre of Excellence, “Cyber Security Strategy Documents,” https://ccdcoe.org/strategies-policies.html.

4. US Department of Homeland Security, Industrial Control Systems Cyber Emergency Response Team, Industrial Control Systems Assessments, FY 2014: Overview and Analysis.

The US Patriot Act of 2001 defines critical infrastructure as “…systems and assets, whether physical or virtual, so vital to the United States that the incapacity or destruction of such systems and assets would have a debilitating impact on security, national economic security, national public health or safety, or any combination of those matters.” According to the US government, there are 16 sectors that fall within this category, including energy, transportation systems, water and waste-water systems, emergency services, dams, critical manufacturing facilities, and chemical facilities.

5. Although companies are inclined to focus significantly on software, the threat of theft or hacking of physical hardware is very real. Use of secure technologies, such as military-grade hard disks and network equipment, can go a long way toward mitigating such threats.

(Excerpted with permission of The Boston Consulting Group (BCG) from the article originally published on www.bcgperspectives.com in March 2016.)

Katharina Rick Partner and Managing Director The Boston Consulting Group - San Francisco Email: rick.katharina@bcg.com Karthik Iyer Principal The Boston Consulting Group - Boston Email: iyer.n.karthik@bcg.com

Offshore World | 41 | December 2018-January 2019

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Municipal or Industrial Flow Solutions The Water Specialties Propeller Meter is the best choice for measuring clean water flows in municipal and industrial applications. The meter is engineered to deliver superior performance, low maintenance and unsurpassed durability.

Meter materials and performance meet or exceed AWWA Standard C704/92.

The Classic Meter for Clean Water Flows Water Specialties Propeller Meters are manufactured using precise techniques and high quality materials. For example, long-life ceramic thrust bearings and a cast bronze gearbox produce the best propeller meter available.

Measurement accuracy is +/-2% of reading. The meter accommodates flow ranges from 35 to 200,000 GPM. The Water Specialties Propeller Meter can be installed vertically, horizontally or inclined, with sizes ranging from 2” to 120”.

Applications Water Specialty Propeller Meters are designed and manufactured with precise techniques and high quality components to deliver superior performance, low maintenance and unsurpassed durability. Materials used on all meters, and flow ranges for low velocity construction meet or exceed AWWA Standards C704/02.

Meters are available for a variety of applications, in sizes 2” through 120”.  Water Well Production  Potable Water  Marine System Testing  Waste Water Management  Pumping Stations  Fire Sprinkler Testing  Canal Laterals  Truck Loading and Discharge Features and Benefits: Electronic propeller meters Water Specialties offer the most radical change in propeller meters in the last 50 years. Our electronic meter offers the latest in technology and simplicity of design. Engineered from the ground up, the electronic meter is light years ahead of its time.

One Moving Part The propeller is the only moving part in the electronic propeller meter. A sensor, which is magnetically coupled to the propeller electronically drives the digital indicator-totalizer.

FlowCom Display Specially designed LCD display can be read in bright sunlight and will not be damaged by prolonged exposures to sunlight. The indicator-totalizer is encapsulated in a moisture resistant barrier so no moisture can come in contact

with the electronic components. This solid state design offers extended life.

Key Features  Proven design for clean water flows  Quality construction  Long-life components  Meets/exceeds AWWA Standard  Accuracy of +/-2% of reading  Wide flow range Long Life Battery The battery has a life of 6 to 10 years.

Transmitter Optional Outputs  4-20 mA  Pulse output  Contact closure Memory The non-volatile memory retains the totalizer quantity and programming.

Installation The electronic meters can be installed vertically, horizontally or inclined Conversion Water Specialties mechanical propeller meters can be converted to electronic propeller meters in the field.

Specifications and Design Features  Accuracy: +/-2%  Flow range from 35 GPM to 200,000 FPS  Right-angled gear drive  Pressure rating up to 300 PSI o  Temperatures up to 350 F  One piece separation and ceramic bearings  O-ring sealed gearbox  Totalizers standard on all meters  Line sizes from 2” to 120”  Indicator-totalizer option available  4-20 mA and pulse rate output transmitter options How it Works The Water Specialties Propeller Meter consists of a rotating impeller positioned in the flow stream. When fluid passes through the meter, it contacts the impeller causing it to spin. The impeller’s rotational velocity is directly proportional to the velocity of the flow.

The rotation is transmitted via a right-angle gear drive to the register, which calculates the flow rate by multiplying the flow velocity with the crosssectional area of the meter tube.

Toshniwal Hyvac Pvt Ltd 267 Kilpauk Garden Road Chennai 600 010 Tel: 044-26445626, 26448983 E-mail: sales@toshniwal.net Website: www.toshniwal.net

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Offshore World | 42 | December 2018-January 2019

PM to lay Foundation Pipeline Product Projects in Odisha

exploration, companies are required to comply with all statutory rules and regulations with regard to environment and other related Acts/Rules.

Before commencing the production activities, Environmental Impact Assessment (EIA) study is to be carried out and necessary environmental clearance is obtained as per the Environment (Protection) Act, 1986 and notification issued thereunder.

The 1212-km long Paradip–Hyderabad Product Pipeline is being built by IOC Ltd at a sanctioned cost of ` 3,800 crores. It is capable of transporting 4.5 MMTPA of petrol, diesel, kerosene and Aviation Turbine Fuel (ATF). The pipeline originates at Paradip and traverses through three States - Odisha (329 km), Andhra Pradesh (723 km) and Telangana (160 km) before terminating at Hyderabad. The pipeline has delivery cum pumping stations at Behrampur, Vizag, Rajahmundry and Vijaywada. The PHPL project will be not only generating employment during its construction, but also ensure efficient transportation of petroleum products across the three States and further cement Paradip’s position as an energy hub of eastern India.

Presently, shale gas exploration is allowed in all the allocated exploration and production blocks in the country. As of now, Oil & Natural Gas Corporation Limited (ONGC) has drilled 23 wells for shale gas exploration and Oil India Limited (OIL) has drilled 4 wells for shale gas exploration under nomination regime. Shale gas/oil exploration in the country is at initial stage and no commercial production of shale gas/oil has been made till date.

Bhubaneswar: Narendra Modi, Hon’ble Prime Minister of India, will lay foundation of Paradip Hyderabad Pipeline Product Project (PHPL) by Indian Oil Corporation Ltd and Bokaro-Angul section of Jagdishpur-Haldia & Bokaro-Dhamra Gas Pipeline Project (PM Urja Ganga) by Gas Authority of India Limited (GAIL) on 24th December 2018 during his visit to Odisha.

The 667-km long Bokaro-Angul pipeline sections of the landmark Jagdishpur-Haldia-Bokaro-Dhamra Pipeline Project (PM Urja Ganga) is being built by the Gas Authority of India Limited at a sanctioned cost of ` 3,437 crores. The pipeline is a part of the landmark Pradhan Mantri Urja Ganga project and traverses 367 Km across 5 districts in Odisha and 360 km across 6 districts in Jharkhand.

Policy Framework Notified to Permit Exploration and Exploitation of Unconventional Hydrocarbons To enlarge the scope of exploration and exploitation of shale gas/oil and other unconventional hydrocarbons, Government has notified the Policy Framework on 20th August, 2018 to permit exploration and exploitation of unconventional hydrocarbons such as shale oil/gas, Coal Bed Methane (CBM) etc. in the existing acreages of Production Sharing Contracts (PSC), CBM Contracts as well as nomination fields to unlock the potential of unconventional hydrocarbons.

The Framework for exploration and exploitation of unconventional hydrocarbons under existing PSC, CBM contracts and Nomination fields” of 2018 provides for ring-fencing of Petroleum Operations and cost recovery from new hydrocarbon discoveries in PSC blocks. Additional 10 per cent rate of Profit Petroleum in case of PSCs and Production Level Payment (PLP) in case of CBM contract, over and above the existing rate of Profit Petroleum/PLP is to be shared with Government on new discoveries.

For nomination blocks, NOCs will be allowed to explore and exploit the unconventional hydrocarbons under the existing fiscal and contractual terms of exploration/lease license. Hydrocarbon Exploration & Licensing Policy (HELP) of 2016 and Discovered Small Field (DSF) Policy of 2015 also provides for exploration and exploitation of unconventional hydrocarbons including shale gas/oil in the acreages to be awarded under these Policies.

The Companies engaged in production of oil and gas employ various technologies, including hydraulic fracturing, for production of oil and gas. While carrying out petroleum operations including shale gas/oil

IIT Bombay, PSU Oil COs Sign MoU to set up Centre of Excellence in Oil, Gas and Energy

Mumbai: A Memorandum of Understanding (MoU) for setting up Centre of Excellence in Oil, Gas and Energy has signed between Director, IIT Bombay and CMDs of PSU Oil Companies and EIL. Dharmendra Pradhan, Union Minister of Petroleum & Natural Gas and Skill Development & Entrepreneurship and Dr M M Kutty, Secretary, Ministry of Petroleum and Natural Gas, graced the occasion.

Speaking on the occasion, Pradhan said the MoU will meet the need of the Mission Green, as it will encourage Research and development in the sector and also do the capacity building. He said that energy is the prime requirement for all activities in the modern world. Indian appetite for energy is increasing day by day, and we have to provide for clean, affordable and accessible energy sources. He said that there is need for mass production through domestic sources, and distribution through decentralization. Pradhan said that the technological and industrial changes are happening ver y fast, and the coming together of the Academic and Industrial organizations gives best results. He said that there is need to put academic research in the entrepreneurial mode, so that results are effective. The Minister said that MoU should be outcome based and must have roadmap for deliverables, and it should set examples for others. He said that India is a large energy market, and effor t should be made to develop our own petroleum standards. We should strive to be leaders in Biomass conversion and Hydrogen based energy. IIT Bombay, being the premier institute, should provide the missing link and help in evolving new strategies in the sector, he added.

To provide a competitive advantage to India’s Oil and Gas industry, Oil & Gas PSUs and IIT Bombay have come together to set up a “Centre of Excellence in Oil, Gas and Energy”. The Centre of Excellence is aimed at collaborative Research & Capability Building in the areas of Oil, Gas & Energy. It will work towards developing sustainable solutions and explore new frontiers in technology for future energy needs. The Centre of Excellence will leverage the expertise available with IIT Bombay and the Oil and Gas industry. It will also provide an institutionalised platform for Industry - Academia interactions. The Centre of Excellence is expected to help in fostering innovations and help in developing a future ready energy industry in the Country.

Offshore World | 43 | December 2018-January 2019

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NEWS

PRESS RELEASES

NEWS

23 Contract Areas under DSF-II awarded

New Delhi: The Empowered Committee of Secretaries (ECS) and Group of Ministers have approved the award of 23 contract areas to Highest Ranked Bidders as part of the Discovered Small Field (DSF) Bid Round – II. The bid submission process under DSF Bid Round – II was successfully completed on January 30, 2019. The bidding under DSF bid RoundII started on 9th August 2018, and 25 contract areas were on offer covering 59 discovered oil and gas fields, spread over 3,000 sqkm with prospective resource base of over 190 MMT (O+OEG).

Under DSF Bid Round-II, a total of 145 bids were received in 24 Contract Areas. As many as 40 companies (Individually or as member of the bidding consortium) have participated in the bid round. 6 foreign companies also participated in the bidding round. This bid round saw more than anticipated participation from new entrants from India and foreign countries like USA, UK, Australia, Singapore and UAE. The bids (online first envelopes and hardcopies) were opened on 30th January 2019 at DGH’s Noida office in the presence of the bidders. The evaluation of the bids was undertaken in a time bound manner and the commercial bids (second envelopes) were opened on 14th February 2019.

Subsequently through detailed process of evaluation, 14 Companies (singly or in Consortium) have been shortlisted for award in 23 Contract Areas. Out of there 14 Companies, eight are new entrants in the E&P Sector.

India to Establish Gas Trading Hub/Exchange

New Delhi: In a bid to push for free trade and supply of Natural Gas through a market mechanisim in India, It has been agreed to establish the gas trading hub(s)/exchange(s) in the country. In view of the administrative, legal, operational issues involved, a precise timeframe for operationalising the gas trading exchange/hub cannot be indicated at this stage.

As per draft National Energy Policy of NITI Aayog, USD 150 billion capital investment is needed in energy sector on an annual basis until 2040. In order to develop the national gas grid, Government has taken a decision to provide a capital grant of ` 5176 crore (i.e. 40 per cent of the estimated capital cost of ` 12,940 Crore) to GAIL for development of a 2655 km long Jagdishpur-Haldia/Bokaro-Dhamra Gas Pipeline (JHBDPL) project.

This pipeline will transport Natural Gas to the industrial, commercial, domestic and transport sectors in the States of Bihar, Jharkhand, Odisha, West Bengal and Uttar Pradesh.

In order to expand City Gas Network in the state of Jharkhand, PNGRB has authorised Bokaro, Hazaribagh & Ramgarh districts geographical area, Giridih & Dhanbad districts geographical area, Ranchi district and East Singhbhoom district at an average investment of ` 400 crore per district during the work plan period.

Oil Public Sector Undertakings (PSUs) namely Indian Oil Corporation Limited (IOCL), Bharat Petroleum Corporation Limited (BPCL) and Hindustan Petroleum Corporation Limited (HPCL) have decided to set up an integrated refinery-cum-petrochemical complex with a refining capacity of 60 MMTPA (Million Metric Tonnes Per Annum) at Babulwadi, Taluka Rajapur in Ratnagiri District in the state of Maharashtra. www.oswindia.com

IGL in Digital Transformation Mode

New Delhi: Dharmendra Pradhan, Minister of Petroleum and Natural Gas & Skill development and Entrepreneurship, Government of India has launched various Digital Customer initiatives of Indraprastha Gas Limited (IGL), including CNG Queue Management System (QMS) and Social CRM. Talking about the countr y’s commitment at COP-21 to reduce the pollution levels, Pradhan announced that Green corridors will soon be unveiled. He said that by Februar y nex t year, CNG buses using Type -IV c ylinders will be running bet ween D elhi-Chandigarh, D elhiAgra, D elhi- Haridwar, and D elhi-Jaipur. He also talked about various initiatives to promote the produc tion and use of Gas, including Ethanol blending, Bio-CNG etc which will improve country’s selfdependence, reduce import bill and clean environment.

Congratulating the IGL for its initiatives, Pradhan said that the company had provided just 4.5 lakh PNG connections till 2014 since its inception, but since then, the growth has been really fast, and the magical figure of 1 million connection has been achieved in just over four and half years.

He said the waiting time for PNG connections has drastically come down to an average of just one week, and people of NCR can now enjoy the clean, convenient and affordable fuel.

Lauding the initiatives of IGL in introducing QMS, Pradhan said that it would tackle the problem of long queues at CNG stations, save time and check the wastage of fuel for waiting vehicles. This will improve the quality of life and enhance income of the vehicle drivers using CNG as fuel. He also congratulated the PNGRB for making a big leap by opening up the City Gas Distribution network in the country that would help almost 400 districts of the country to have piped gas supply.

Pradhan said that ` 70,000 Crore is being invested in the CGD network in the country. He said that the Government has given top priority to providing gas supply to domestic sector and it was one of the first decision taken by the Government to provide domestic gas at the domestic price and not the imported price. He said that there are 1500 CNG stations in the country, including 450 in Delhi. The number of CNG stations in next 4-5 years is likely to go up to 10,000, he added.

The CNG Queue Management System through “OORJA” mobile application would provide information regarding the average waiting time at the CNG station and also alternative nearby CNG Station to the customers. The customers would know the waiting time for three broad categories i.e. Buses, Cars and Autos. They will also be able to see CNG Station nearby and the waiting time for three categories of vehicles. This application would be available through invitation initially for ten days and would be available for download from 1st Jan. 2019.

The Technology platform—Social CRM will address customer queries, complaints, service requests, grievances on various social media platforms, such as facebook, twitter and Instagram. This can be used to effectively view and monitor the grievance redressal process by using the sentiment analysis.

Offshore World | 44 | December 2018-January 2019

The Cabinet Committee on Economic Affairs, chaired by the Prime Minister Shri Narendra Modi, has given its approval to the project for capacity expansion of Numaligarh Refinery from 3 MMTPA (Million Metric Tonne Per Annum) to 9 MMTPA. It involves setting up of crude oil pipeline from Paradip to Numaligarh and product pipeline from Numaligarh to Siliguri at a cost of ` 22,594 crore. The project is to be completed within a period of 48 months, after approval and receipt of statutory clearances.

The expansion of the refinery will meet the deficit of petroleum products in the North East. It will also sustain the operations of all North East refineries by augmenting their crude availability. It will generate direct and indirect employment in Assam and is a part of the Government’s Hydrocarbon Vision 2030 for the North East.

Open Acreage Licensing Programme Bid RoundII Launched New Delhi: Dharmendra Pradhan, Union Minister of Petroleum and Natural Gas & Skill Development and Entrepreneurship, has launched NIO and MRSC for Open Acreage Licensing Programme (OALP) Bid Round-II. In this bid round, 14 E&P blocks, with an area of approximately 30,000 sqkm, are being offered for bidding to the investor community under the investor friendly HELP regime. 10 blocks are based on Expressions of Interest submitted by the bidders, and 4 blocks have been car ved out by the Government based on data received through the National Seismic Programme and the Resource Reassessment Study carried out by the Government.

Speaking on the occasion, Pradhan said that the energy requirement of the countr y is increasing ver y fast, and we are mainly dependent on impor ts for fulfilling our fuel and transpor tation fuel requirements.

E&P sector has been a challenge, and the Government has under taken a large number of reforms to bring in more investment and increase domestic production. Almost 60,000 sqkm area was offered under OALP Bid round I and 30,000 sqkm more is being offered under the second round, while the third round is almost ready.

He said that earlier the decision about exploration was based on the potential Government revenue, but didn’t yield much results. Now, the Government is working to increase production. For this purpose, IOR/EOR has been announced, production enhancement contract model is being worked out. The Minister said that more fiscal incentives will be given for increasing the production, and difficult fields will be given special incentives. Pradhan said that more transparency has been brought about in policy making and stakeholders are being consulted. He said that National oil companies will be encouraged to increase production, but at the same time, they will have to be more accountable and responsible.

He called for setting up of Indian standards for petroleum with respect to quality, safety and other aspects which should usher in innovations. He expressed the hope that the investors will whole-heartedly participate in the bidding rounds, bringing in more investments, creating jobs and improving self-sufficiency and scientific capacity.

India is 3rd largest energy consumer in the world and likely to have one of the fastest growing energy demand of the world in the coming years. As a step to meet this growing demand and in line with Prime Minister’s vision of achieving Energy Security and Sufficiency, the Ministr y of Petroleum and Natural Gas (MoPNG) has steered a plethora of reforms in the recent past years. The Hydrocarbon Exploration and Licensing Policy (HELP) replacing the erstwhile New Exploration Licensing Policy (NELP) was approved in March 2016 and the Open Acreage Licensing Programme (OALP) along with the National Data Repositor y (NDR) were launched in June 2017 as the key drivers to accelerate the Exploration and Production (E&P) activities in India.

The programme envisages six monthly periodic bidding rounds starting from July 1, 2017.

The first bidding round under OALP (Bid Round I) was launched in January 2018 and closed in May 2018 and 55 blocks covering 59,282 sqkm area were awarded in October 2018.The Government is also in advanced stages of finalizing the OALP Bid Round III with approximately 32,000 sqkm of area and the bidding is expected to be launched within next few weeks.

With this successful roll out of the HELP/OALP regimes, together with the National Data Repository (NDR), the Government has achieved a massive addition to the exploration acreage of India. The acreage which stood at approximately 90,000 sqkm in 2017 was increased to 150,000 sqkm after OALP I and would touch 2,10,000 sqkm after OALP Round II and III bidding exercises by May 2019 and is expected to touch 300,000 sqkm by the end of the year 2019, with another two rounds of bidding expected to be finalized (IV and V) in 2019.

The licensing programme under HELP which adopts the Revenue Sharing Model is a step towards improving the ‘Ease of Doing Business’ in the Indian Exploration and Production (E&P) sector. It comes with attractive fiscal terms like reduced royalty rates and no oil cess, marketing and pricing freedom, submission of Expression of Interests (EoIs) round the year, bid rounds commencing every six months and a single license to cover conventional and unconventional hydrocarbon resources.

With the launch of Notice Inviting Offer (NIO), bidders can study the data available in National Data Repository (NDR) and select blocks for the bidding. The bidders would be able to submit their bids through an online e-bidding portal starting 8th January 2019 and the bidding round would continue till 12th March 2019. The blocks are spread across 7 sedimentary basins, 14 blocks are on offer under OALP-II which includes 8 blocks (Onland), 5 blocks (Shallow Water) and1 block (Ultra-Deep Water). It is expected that OALP Round II would generate immediate exploration work commitment of around USD 500-600 million.

Offshore World | 45 | December 2018-January 2019

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NEWS

NRL to augment its Capacity

PRODUCTS Process Heating Control & Monitoring Thermon Group Holdings, Inc (Thermon) offers TraceNet Genesis Control & Monitoring System, a new solution for managing heat trace circuit performance on process lines, tanks and instrumentation.

The TraceNet Genesis System gives instant access to comprehensive heat trace circuit information, including circuit performance history, fault analysis, and circuit drawings. Using this information, maintenance personnel can predict failures avoiding downtime or quickly restore operations minimizing downtime.

The TraceNet Genesis System provides instant on-panel access to heat trace circuit performance trending and histories of up to 6 months, for up to 72 heat trace circuits. Until now, this capability was only available by networking back to a remote computer.

A six-month history that reflects, eg, fluctuations or a steady decay in temperature could indicate that the system requires inspection to see whether the thermal insulation is being compromised or if an individual heater is not operating properly. By analyzing this data, maintenance engineers can assess the timing, process operating conditions, and any undesirable symptoms as an early indicator of a future problem. This type of data is critical to effective circuit and overall system maintenance.

Another unique feature of the TraceNet Genesis System lies in its ability to allow circuit isometric drawings to be stored and viewed locally, at the heat trace panel. As a result, maintenance engineers can quickly determine the circuit’s precise location and quickly respond to alerts. For the first time, isometric drawings need not be viewed from a remote computer monitor, but are presented on the local TraceNet Genesis touchscreen at the panel.

The TraceNet Genesis System includes an easy-to-navigate touchscreen user interface. With a single touch, the user can easily navigate into circuit details in order to modify set points, manage alarms, see trending or view a drawing.

For details contact: Thermon San Marcos, Texas, U.S.A. Tel: +1 512-396-5801, Ext: 2239 E-mail: lance.bielke@thermon.com / contact sales@thermon.com

Direct Drive Electronic Elesa+Ganter wide range of standard machine elements has recently extended its range of electronic position indicators by introducing the new DD52R-E that joins the DD51-E model.

Elesa+Ganter electronic position indicators are characterized for their wide orientable display (DD51-E – 5 digit of 8,0 mm height and DD52R-E – 6 digit of 12,0 mm height) that ensures excellent readability even from a distance and from different viewing angles.

The AISI 304 stainless steel bushing ensures a high corrosion resistance.

Diameter: DD51-E – 14 mm and DD52R-E – 20 mm.

The internal lithium battery ensures a long life: DD51-E of over 5 years and DD52R-E of over 8 years.

The battery replacement can be performed easily, without disassembly of the indicator from the control shaft and without the loss of parameter configuration.

The window in transparent technopolymer moulded over the case protects the LCD display against accidental shocks. The ultrasonic welding between the base and the case avoids dust and liquids penetration offering a high IP protection class (IP65 or IP67). For this reason the electronic position indicators are suitable for applications that require frequent washing, even with water jets.

Thanks to the available functions and the programmable parameters, one item can be used for many applications.

For details contact: Elesa and Ganter India Pvt Ltd A-54, Sector-83 Noida, Uttar Pradesh 201 305 Tel: 0120-4726666 Fax: 91-0120-4726600 E-mail: info@elesaganter-india.com www.oswindia.com

Offshore World | 46 | December 2018-January 2019

PRODUCTS Electromagnetic Flow Meter

Thermal Mass Flow Meter

Process Control Devices offers a Series of digital flow meters.

Designed to measure the flow rate of liquids flowing through the closed pipe. The electromagnetic flow meter is volumetric flow meter having no obstruction as there are no moving parts. Hence, pressure drop is negligible. The performance is independent of density, viscosity, temperature and pressure of the flowing liquid. The magnetic flow meter is calibrated using water and can measure the flow of other conductive fluids, with no further correction. This is a special feature that other type of flow meters does not have.

Thermal Mass Flow Meter is accurate, easy to install, having no moving parts and best suitable solution for measuring and controlling compressed air, oxygen, nitrogen, biogas, digester gases, ethane and natural gas flow. Heat dispersion (mass flow) technology provide proportional mass flow measurement resulting in higher accuracy performance at a lower cost than orifice flow meter, Vortex shedding flow meter and other gas flow measuring devices.

Electromagnetic flow meters work on the principle of Faraday’s Law of electromagnetic induction. According to the law, when a conductive liquid cut the magnetic field, voltage induces. Further, that voltage signal is sensed by the electrode which is mounted on the wall of the flow tube. That induced voltage signal is processed by the electronic transmitter to determine the flow.

The generation of voltage is directly proportional to the velocity of the fluid.

The thermal principle operates by observing the cooling effect of a gas flow as it passes over a heated transducer. The temperature sensor monitors the actual gas temperature whilst the heater transducer is maintained at a constant differential temperature by caring the required current from electronic to maintain the differential temperature. Greater the flow, greater will be cooling effect and power required to maintain the differential temperature. The energy required maintaining this temperature differential is directly proportional to the mass flow rate. Thus, there is no need for additional temperature or pressure compensation in thermal mass flow meter. This meter is also used for compressed air flow measurement.

For details contact: Process Control Devices Plot No: 22, Rautara Indl Estate B/s Hanuman Hotel, Shil-Mahape Road Shilphata, Thane, Maharashtra 400 612 E-mail: sales@pcd-flowmeter.com / sales.pcdpl@gmail.com

For details contact: Process Control Devices Plot No: 22, Rautara Indl Estate B/s Hanuman Hotel, Shil-Mahape Road Shilphata, Thane, Maharashtra 400 612 E-mail: sales@pcd-flowmeter.com / sales.pcdpl@gmail.com

Oxygen Permeation Analyzer AMETEK MOCON offers OX-TRAN 2/40 oxygen permeation analyser for whole package testing of cups, trays, pouches and other forms. AMETEK MOCON offers a new analytical instrument to measure the oxygen transmission rate (OTR) of whole packages under precisely controlled environmental conditions. The new OX-TRAN 2/40 Oxygen Permeation Analyzer for OTR measurements targets package permeation testing for food, beverage and healthcare packaging applications in which knowing the precise oxygen ingress through a package is critical to a product’s shelf life. Applications for the OX-TRAN 2/40 include permeation testing of thermoformed trays, bottles, flexible pouches, corks, caps, and more.

Historically, testing the oxygen permeation of whole packages either suffered from poor control of the test gas conditions, since the package was tested in room air, or required cumbersome set up of an independent environmental chamber that was often difficult to use. Adding to the complexity of legacy package permeation testing, package samples needed to be epoxy adhered and heat removed from reuseable plates. The OX-TRAN 2/40 utilizes MOCON’s industry-standard coulometric sensor, so no calibration is required, and it complies with ASTM F1307 for OTR measurements.

For details contact: AMETEK Inc 1100 Cassatt Road, Berwyn Pennsylvania 19312, U.S.A. Tel: +1-763-493-7238 E-mail: jamie.durkin@ametek.com Offshore World | 47 | December 2018-January 2019

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PRODUCTS Indexing Plungers Corrosion resistance, hygiene and material quality are properties which are highly appreciated in the pharma and food industry, in hospital engineering, fresh water supply and waste-water engineering, the aerospace industry, conveyor engineering and in machine and plant construction. For these industries ELESA+GANTER’s standard machine elements has added to its product range of index plunger models GN 613 / GN 617 and GN 617.1 the design variant with stainless steel knob - the first all stainless steel index plunger. The GN 613 indexing plungers have no collar and boast extremely small dimensions, designed to absorb axial forces in their end position.

The GN 617 and GN 617.1 indexing plungers are each fitted with a collar, with the GN 617.1 indexing plunger featuring an additional indexing lock. These are used if the index pin is temporarily not allowed to protrude. To engage, the knob is turned by 90° after pulling out. An index notch prevents the disengaged knob inadvertently turning back under the impact of vibrations. All stainless steel indexing plungers are made in consistently high quality and feature a long service life.

Options - Ganter offer include the holding fixtures GN 612.1 and GN 412.1 as mounting aids for indexing plungers, cam action-indexing plungers and positioning bushings (GN 412.2).

For details contact: Elesa and Ganter India Pvt Ltd A-54, Sector-83 Noida, Uttar Pradesh 201 305 Tel: 0120-4726666 Fax: 91-0120-4726600 E-mail: info@elesaganter-india.com

Sheet Metal Structured Packing EVERPACK SM Column Packing is the sheet metal version of the popular EVERPACKWM (wire mesh) and HYFLUX (knitted wire mesh) packing. Their development is a part of EVERGREEN’s continuous and comprehensive development program to improve column packing performance.

EVERPACK SM is supplied in modules, which consists of parallel layers of uniquely designed embossed sheet metal strips which are corrugated and arranged vertically. These modules are then stacked with an alternating 90 degree orientation of every other layer which gives a good lateral distribution of liquid. The embossed metal strips help to draw the liquid in all directions into a thin film and provides a marked improvement in uniform wetting of the packing bed.

With the improved internal liquid distribution, high volumetric mass transfer efficiency is achieved and low pressure drop is maintained. Also because liquid is evenly distributed through the packing as a thin film, the total liquid hold-up in the packing is substantially reduced.

The standard packing version has specific surface area of 250 m 2/m 3 (EVERPACK SMY 250). However, other variants with specific surface areas of 125 m 2/ m 3 (SMY 125), 175 m 2/m 3 (SMY 175), 350 m 2/m 3 (SMY 350), 500 m 2/m 3 (SMY 500), 750 m 2/m 3 (SMY 750) and X crimp (60 degree crimp alignment) are also. Evergreen Technologies Pvt Ltd also manufacture high efficiency column internals (distributors, collectors, support grids, etc). Good initial distribution together with systematic redistribution is critical to optimum tower performance.

It finds application in vacuum distillation where relatively low pressure drop is critical to maintaining low bottom temperatures to reduce products degradation; atmospheric operations where a large number of theoretical stages are required and/or where there are restrictions to overall column height; debottlenecking/energy reduction programs with the advantages of a high efficiency packing used to reduce reflux requirements and increase throughputs; and increase product purity which is possible due to availability of more equilibrium stages from same size column.

For details contact: Evergreen Technologies Pvt Ltd 3-D, Maker Bhavan-2 18 New Marine Lines Mumbai 400 020 Tel: 022-22012461, 22012706, 61566969 Fax: 91-022-22010024 E-mail: info@evergreenindia.com www.oswindia.com

Offshore World | 48 | December 2018-January 2019

EVENTS DIARY

West Africa International Petroleum Exhibition & Conference Date: 23-14 Januar y 2019

Venue: Eko Convention Centre, Lagos Event: The West African International Petroleum Exhibition and Conference ( WAIPEC) will return to the Eko Convention Centre 23-24 Januar y 2019 as the only oil and gas event held in par tnership with Nigeria’s petroleum industr y. Working direc tly with PETAN, the organisers will draw on their global resources to ensure that the event delivers to the needs of all stakeholders in Nigeria and through the region.

13th Edition Petrotech 2019 Date: 10-12 February 2019 Venue: India Expo Mart, Greater Noida, NCR, New Delhi Event: The Petrotech series of International Oil and Gas Conference and Exhibition is biennial platform for National and International experts in oil and Gas Industry to exchange views and share knowledge, expertise and experiences, exploring areas of growth in the energy value chain. Being held for the last over two decades with growing participation, PETROTECH-2019 is the 13th edition of the flagship event of the bustling Indian hydrocarbon sector that is a must-attend one in this part of the globe.

WAIPEC 2018 was the largest petroleum event of its kind in West Africa, as the cit y of Lagos welcomed in thousands of key regional stakeholders - plus leading international E&P firms and par tners - to develop and drive new business across the sec tor.

The event aims to explore areas of growth in petroleum technology, exploration, drilling, production and processing, refining, pipeline transportation, petrochemicals, natural gas, LNG, petroleum trade, economics, legal and human resource development, marketing.

For details, contact: PETAN T: 080 372 55190 E: adejumoke.oyedun@petan.org

For details, contact: Phone: +91-11-26754994 Email: secretariat@petrotech.in

2 nd Morocco Oi l & Gas Summit 2019

SPE Oil and Gas India Conference and Exhibition

Date: 6-7 Februar y 2019

Venue: Radisson Blu Hotel, Marrakech, Morocco Event: IN-VR O il & G as is pleased to announce the second edition of ONHYM’s official oil and gas conference “Morocco O il & G as Summit”. Under the auspices of The National O ffice of Hydrocarbons and M ines (ONHYM) , IN-VR O il & G as is honoured to carr y out the 2nd “Morocco O il & G as Summit” on 6 th - 7 th Februar y 2019 in Marrakech, Morocco.

For the first ti me, companies will discuss Morocco’s Atlantic offshore geology and the results recent exploration ac tivities are showcasing, onshore exploration and unconventional hydrocarbons oppor tunities.

They will cover all exploration challenges and oppor tunities in Morocco, including how E&P companies and contrac tors can make the most out of the current experienced lowcost ser vice environment in Morocco. O ppor tunities for independent O il companies will be shared, including the great investment potential of shallow offshore fields for smaller exploration companies.

For details, contact: Organiser: IN-VR Oil & Gas Website: http://w w w.morocco-summt.com E-mail: lydia@in-vr.co; marketing@in-vr.co

Date: 9 - 11 April 2019 Venue: Mumbai, India Event: The SPE Oil and Gas India Conference and Exhibition is a wellrecognised event which aims to bring together the latest advances and best practices in the oil and gas industry.

The previous edition in April 2017 was organised with the theme, “Managing E&P Business in the Changing Environment” and was very well-received by local and international oil and gas professionals. We received more than 600 delegates from 121 companies, and 23 countries.

The conference offers a unique platform to raise your company’s profile within the industry and creating greater awareness of your brand. Take advantage of this opportunity to promote new and existing products and services to key professionals in the industry.

For details, contact: Khushbu Rajwani Tel: 022-66927777 Fax: 022-66928899 Email: dubprog@spe.org

Offshore World | 49 | December 2018-January 2019

www.oswindia.com

BOOKSHELF

The Hitchhiker’s Guide to the Upstream Oil & Gas Industry

Author: Bernhard W Seubert Price: $24.00 No of pages: 190 pages (Paperback) Publisher: Independently published About the book: This book has been written for laymen, for all those who would like to understand the business of oil and gas without having to read through the ballast of technical background. This book is easy to read and nearly free of technical jargon and mathematical formulas. To help with understanding, a glossary has been added as an appendix. The book is meant as an introduction to the large field of geology and upstream petroleum technology. It addresses investment people, students, non-technical managers in an oil company, journalists and all those who want to obtain a quick immersion into the oil and gas industry. If you are in the oil and gas business and need to explain to someone outside the field – this is intended for you. If you are a non-technical person in an oil company or are considering studying geology or petroleum engineering, this is the fastest way to read up on the subject matter. For the seasoned professional who is familiar with the subject matter, this book may come in useful to explain aspects of the business to outsiders. A special effort has been made to point out the stochastic nature of exploration, the value of information and knowledge and the economic and historic back-drop on which all commercial oil and gas operations take place. This book does not claim to be complete and correct to the last detail. Indeed, some aspects have been drastically oversimplified to make them easier to understand. For further study and for those who want to know more, there is a large body of books, teaching videos and webinars on the Internet in additions to commercial libraries. In fact, every aspect of the oil business is so rich in detail and profound in science that it requires study and specialists’ knowledge. The subject of every chapter could be a full career or profession.

Introduction To Petroleum Exploration And Engineering Author: Andrew Clennel Palmer Price: Paperback $38.00 No of pages: 154 pages (Paperback) Publisher: WSPC About the book: This book is an introduction to oil and gas designed to be both accessible to absolute beginners who know nothing about the subject, and at the same time interesting to people who work in one area (such as drilling or seismic exploration) and would like to know about other areas (such as production offshore, or how oil and gas were formed, or what can go wrong). It begins by discussing oil and gas in the broader context of human society, and goes on to examine what they consist of, how and where they were formed, how we find them, how we drill for them and how we measure them. It describes production onshore and offshore, and examines in detail some instructive mishaps, including some that are well known, such as Deepwater Horizon and Piper Alpha, and other lesser known incidents. It looks at recent developments, such as shale oil, and concludes with some speculation about the future. It includes many references for readers who would like to read further. Mathematical content is minimal.

Production Chemicals for the Oil and Gas Industry Author: Malcolm A Kelland Price: $120.73 No of pages: 454 pages (Hardcover) Publisher: CRC Press (2nd Edition) About the book: Production chemistry issues result from changes in well stream fluids, both liquid and gaseous, during processing.

Since crude oil production is characterized by variable production rates and unpredictable changes to the nature of the produced fluids, it is essential for production chemists to have a range of chemical additives available for rectifying issues that would not otherwise be fully resolved. Modern production methods, the need to upgrade crude oils of variable quality, and environmental constraints demand chemical solutions. Thus, oilfield production chemicals are necessary to overcome or minimize the effects of the production chemistry problems.

This book discusses a wide variety of production chemicals used by the oil and gas industry for down-hole and topside applications both onshore and offshore. Incorporating the large amount of research and applications, this new edition reviews all past and present classes of production chemicals, providing numerous difficult-to-obtain references, especially SPE papers and patents. Unlike other texts that focus on how products perform in the field, this book focuses on the specific structures of chemicals that are known to deliver the required or desired performance - information that is very useful for research and development. Each updated chapter begins by introducing a problem, such as scale or corrosion, for which there is a production chemical. The author then briefly discusses all chemical and nonchemical methods to treat the problem and provides in-depth descriptions of the structural classes of relevant production chemicals. He also mentions, when available, the environmental properties of chemicals and whether the chemical or technique has been successfully used in the field. This Edition includes two new chapters and nearly 50 per cent more references.

www.oswindia.com

Offshore World | 50 | December 2018-January 2019

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