YoungPetro - 20th Issue - Summer 2017

SPRING/ 2017 ISSUE #20

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What a wonderful year of anniversaries. For the 20th time YoungPetro is reaching to you, our dear readers, and the motherland of the magazine, the AGH UST Faculty of Drilling Oil and Gas, is celebrating its 50th birthday. Due to that I would like to express my gratitude to my colleagues who started creating this wonderful project seven years ago, to my wonderful team of editors who is doing their best to make YP happen every season of the year, our Ambassadors who are spreading this around the world, and finally to you, our readers, for constant support and attention.

This Issue will be filled with informative articles.

Thanks to our talented friends from India you will be able to extend your knowledge in the area of Drilling Engineering and EOR methods. As always you will be able to check the news from Oil & Gas Industry in ‘On stream’ and refresh your knowledge with ‘How it works’.

Athanasios Pithatzis will share with you his experiences from UK’s energy market and Wojciech Panek will give you a sneak peak of gas networks stimulations.

If you were not given the opportunity to visit Oil & Gas Horizons in Moscow or Student Technical Conference, which was held in Wietze, Germany or you simply want to remind how great memories you have from there – the solution in in your hands.

Finally, if you would like to get some rest form absorbing the knowledge, you can reach for Fayaz Ahmed’s column which is in a smart way comparing the actual situation in our Industry to the plot of very popular HBO series ‘Game of thrones’. In conclusion, I would like to wish you- a fruitful spring, my successors- further years of publishing and all of us- a lot of successes because ‘Winter is (certainly not) coming…’

Enjoy!

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Editor-in-Chief Natalia Krygier n.krygier@youngpetro.org Deputy Editor-in-Chief Patryk Bijak p.bijak@youngpetro.org Art Director Alicja Pietrzyk alicjaa.pietrzyk@gmail.com Editors Wojciech Kurowski Jakub Pitera Monika Saczyńska Graphic designer Patrycja Lanc

Ambassadors Josiah Wong Siew Kai - Malaysia Alexander Scherff – Germany Viorica Sîrghii - Romania Athansios Pitatzis – Greece Sagar Karla- India Alex Zakrzewski- UK Muhammad Bilal Akram- Pakistan Serhii Kryvenko- Ukraine/ Texas, USA Alahdal A. Hussein- Malaysia Ivan Bošnjak- Croatia Publisher Fundacja Wiertnictwo - Nafta - Gaz, Nauka i Tradycje Al. Adama Mickiewicza 30/A4 30 - 059 Kraków, Poland www.nafta.agh.edu.pl

Proof-reader Adam Sikorski

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Marketing Filip Czerniawski Maksymilian Łękowski Karolina Zahuta

2300-1259

Published by

An Official Publication of

The Society of Petroleum Engineers Student Chapter P o l a n d • www.spe.net.pl

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On Stream – Latest News

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Patryk Bijak

Parallels Between Game of Thrones and Oil Prices

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Fayaz Ahmed

Simulation of a gas network

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Wojciech Panek

UK Energy Sector, Current Risks and Future Challenges 13 Anthanasios Pitatzis

Paris Agreement: Yes We Can? 19 Alex Zakrzewski

Introduction to Snake Wells with Particular Focus on Rotatory Steerable System 23 Aditya Prabha, Kartik Mangwani, Manpreet Singh

Scale Formation Problems in Oil & Gas Industry: Its Reduction Procedures by 34 Chemical Introduction Sachin Nambiar, Vivek Thakar

Employing Alkaline Surfactant Polymer in Chemical Enhanced Oil Recovery 43 Tarun Kumar, Kishan Kumar Gupta, Akshita Agarwal

How We Do It in Romania? 52 Corlean Oana-Alexandra, Gheorghe Alin-Marian, Balanescu Alexandra Laura

‘Oil and Gas Horizons’ 2016 56 STC 2016, Wietze, Germany 60 How It Works? 64 Wojciech Kurowski

On Stream – Latest News

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On Stream – Latest News Patryk Bijak

New Technology in Methane Leak Detection Can Save a Fortune Yearly the global sum of losses caused by methane leak reaches up to US$30 billion. In order to optimize costs, a new technology has been deployed by Statoil at a field in Eagle Ford. Gas leak monitoring system developed by Quanta3, a startup from Colorado, uses tunable laser diodes to detect the release of methane in the air and transfers the data to the operator via the cloud. The solar-powered system is in the testing phase now, aiming to ensure 24-hour monitoring and detection. Another laser based technology is being developed jointly by three research institutions: the University of Colorado Boulder, the University of California Davis, and the National Institute of Standards and Technology. The system, which can send laser beams over distances of up to one mile, can detect methane concentrations in the atmosphere with an accuracy rate of one part per billion. In addition to the ground equipment, there will be also measured methane concentration in the air to estimate the total emissions of the gas at production and storage sites. According to the Environmental Defense Fund, there are another 17 laser-based detection systems developed simultaneously.

Cuba Opens Up for Foreign Investments Cuba’s government is wasting no time, after the U.S. lifted their trade embargo, and is currently trying to attract foreign investors to their energy industry, with a particular focus on offshore drilling. Accor-

ding to the deputy general director of a state-owned company Cuba Petrol Union (CUPET), Roberto Suarez, about 50 percent of the island’s demand is being covered by local production, but the plans are to raise this substantially in the near term. New discovers have recently been made in the North Belt shelf, a 200-km-long offshore area east of Havana, and CUPET is looking for partners that will bring in new technologies to its oil industry. $7B Pipeline Project May Be Suspended Iran has said that it may suspend its US$7-billion ‘peace pipeline’ project with Pakistan due to construction delays. If negotiations fail, the project could be cancelled entirely. Negotiations started over 15 years ago with India involved in the gas pipeline project, too; however, Pakistan and Iran finally signed the initial agreement in 2009 while India abandoned it. Since then Iran’s neighbour hasn’t finished the construction on its side. Pakistan already has a growing energy crisis and the project is crucial if they are to obviate it. Another obstacle in making the project feasible is the gas price, which is too high, as Pakistan claims, and Turkmenistan can offer lower prices than Iran does through the TAPI pipeline. The talks concern the transit of up to 22 million cubic meters of gas a day.

Fayaz A

st News

Fayaz Ahmed

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Parallels Between Game of Thrones and Oil Prices Fayaz Ahmed

** Kuwait Foreign Petroleum Exploration Company ÞÞPakistan fzahmed@kufpec.com  University  Country  E-mail

The uncertainty in the Game of Thrones which has made fans go totally gaga over the show is the very same factor making oil price fluctuations very interesting. May it be Ned’s untimely execution, Rob and Catelyn’s cold-blooded murder, John’s death prior to resurrection, and burning of the Great Sept of Baelor into ashes

by Cersei. I bet nobody saw those things coming while watching the show. Same goes for oil prices; you never know which way oil price rollercoaster is going to move. After June 2014, 100 $/bbl oil started tumbling and within no time oil prices hit 14-years-record lows to 26.21 $/bbl in February 2016.

OPEC has had the great time ruling the oil market of above 100$/bbl for long until shale phenomenon popped up around the world, especially in the US. Shale producers started gushing the market with too much oil eventually crashing oil prices very badly. This time even OPEC lead by Saudi finds it challenging to stabilize the market without losing their market share.

OPEC and Cersei share great deal of similarities with each other, they both are ambitious and desperate to maintain their dominancy at all costs.

As Cersei didn’t hesitate to reduce the Sept of Baelor to ashes for killing her enemies (High Sparrow, Marjaery) in the finale of the sixthsSe-

ason, Saudi also flooded the oil market with an attempt to lower down oil prices to a level where their opponents (US Shale Producers) could run out of business, which didn’t happen. Shale Producers survived even below 30$/bbl due to their resilience and cost-effectiveness reducing rig count to half without significant production decline.

Unfortunately, OPEC like Cersei ended up having nothing but pain in their assess; Cersei lost her only remaining child while OPEC lost decades of strong hegemony over the oil price market.

On the other hand, the US like John Snow is just getting started with the shale boom. You do remember when John marched north of the wall and fought with ferocious wildings and white walkers.

People started speculating about how long he will be able to survive in that rough environment. He proved all the speculations wrong with his relentless struggle for survival and sheer resilience; not only did he return to Castle Black unscathed but also escaped death when betrayed by the brothers of Night Watch. US Shale Producers have been going through the same scenario, OPEC has done everything possible to suppress shale production from the US to maintain their market share, OPEC assumed that lower oil prices won’t allow the US to produce hydrocarbons from high cost Unconventional Plays and eventually their production would decline but no significant decline has been seen during this downturn.

The bad news is everybody wants to pump more oil to retain their market share with already overflooded market. After couple of failed attempts, OPEC has finally agreed to limit their production to 32.5 MMbbls/day from current production of 33.24 MMbbls/day to ease the glut. I am afraid this time market dynamics are different, and

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Simulation of a gas network  Wojciech Panek Simulation of a gas Parallels networkBetween Game of Thrones and Oil Prices  8  AGH University of Science and Technology  Wojciech Panek  Poland  OPEC able to stabilize oil market klehigh-methane expected surgegas in the US output This if oilgas prices At present inbeMałopolska theScience number of alone consumers of is increasing. is AGH University of and Technology  won’t in their traditional due to the following im- With the improve postofsuccessful freeze Although this supplied

by Polska ways Spółka Gazownictwa Sp.z o.o. growth the number of deal? new clients arises  Poland mediate challenges: How will OPEC be able to freeze deal has given a lot of hope in petroleum the question as to whether in some sections of the gas distribution network the pressure won’t fall implement freeze deal when their own house is have gas? circles forkind improving I don’t under the safety level, andthe will the customers This of doubts emergebut especially inis At present in Małopolska number of consumers of high-methane gasoilis market; increasing.

This gassee not in order?

What if Russia doesn’t comply with that thing happening anytime sooner.

I bet “Winter autumn and winter because the drop in temperature automatically increases the consumption of the supplied by Polska Spółka Gazownictwa Sp.z o.o. With the growth of the number of new clients arises output cap proposed bysituations OPEC?inHow they tac-oftothe is Comingâ€?. blue energy.

Inassuch it iswill necessary perform static simulation thepressure gas network.

In the question to whether some sections gas distribution networkofthe won’t fall order to perform this task, engineers use computer softwares such as SimNet, or SONET software. under the safety level, and will the customers have gas? This kind of doubts emerge especially in The last one thebecause engine of the GASNET program. automatically increases the consumption of the autumn anduses winter the drop in temperature blue energy. In such situations it is necessary to perform static simulation of the gas network. In in the [kPa] order toType perform this task, engineers use computerPressure softwares suchnetwork as SimNet, or SONET software. of pipeline Minimal Maximal The last one uses the engine of the GASNET program.

Low-pressure 1,8 10 Pressure in the network [kPa] Medium-pressure 100 500 Type of pipeline Minimal Maximal Upper medium-pressure 500 1600 Low-pressure 1,8 10 High-pressure 1600 10000 Medium-pressure 100 500 Upper medium-pressure

500

1600

Pressure network Tab. 1 The divisionof of the pipelines by maximum work pressure

High-pressure

1600 High

10000 Low

Medium

Mathematical features of the network Pressure of the network đ?‘§đ?‘§ ŕľŒ đ?‘§đ?‘§áˆşđ?‘?đ?‘?ÇĄ đ?‘‡đ?‘‡ÇĄ đ?‘‘đ?‘‘áˆť đ?‘§đ?‘§ ŕľŒ Íł Compressibility factor High Medium Lambda Compressibility factor Pressure drop Lambda

đ?‘˜đ?‘˜ đ?‘˜đ?‘˜ Mathematical đ?œ†đ?œ† ŕľŒ features đ?œ†đ?œ†áˆşđ?‘…đ?‘…đ?‘’đ?‘’ÇĄ đ??ˇđ??ˇ )of the network đ?œ†đ?œ† ŕľŒ đ?œ†đ?œ†áˆşđ?‘…đ?‘…đ?‘’đ?‘’ÇĄ đ??ˇđ??ˇ ) đ?‘¤đ?‘¤ đ?‘¤đ?‘¤ đ?‘§đ?‘§ ŕľŒ đ?‘§đ?‘§áˆşđ?‘?đ?‘?ÇĄ đ?‘‡đ?‘‡ÇĄ đ?‘‘đ?‘‘áˆť đ?‘§đ?‘§ ŕľŒ Íł đ?‘?đ?‘?ͳʹ − đ?‘?đ?‘?Í´Í´ ŕľŒ đ?‘“đ?‘“áˆşđ?‘„đ?‘„đ?‘›đ?‘›Í´ áˆť đ?‘?đ?‘?ͳʹ − đ?‘?đ?‘?Í´Í´ ŕľŒ đ?‘“đ?‘“áˆşđ?‘„đ?‘„đ?‘›đ?‘›Í´ áˆť

Pressure drop Calculation of flow velocity

Calculation of pressure gradient

đ?‘˜đ?‘˜

đ?œ†đ?œ† ŕľŒ đ?œ†đ?œ†áˆşđ?‘…đ?‘…đ?‘’đ?‘’ÇĄ đ??ˇđ??ˇ ) đ?‘¤đ?‘¤ Profile of results

đ?‘?đ?‘?ͳʹ − đ?‘?đ?‘?Í´Í´ ŕľŒ đ?‘“đ?‘“áˆşđ?‘„đ?‘„đ?‘›đ?‘›Í´ áˆť Not necessary

Profile of results Non-essential

đ?‘˜đ?‘˜

đ?œ†đ?œ† ŕľŒ đ?œ†đ?œ†áˆşđ?‘…đ?‘…đ?‘’đ?‘’ÇĄ đ??ˇđ??ˇ ) đ?‘¤đ?‘¤

đ?‘?đ?‘?ͳʹ − đ?‘?đ?‘?Í´Í´ ŕľŒ đ?‘“đ?‘“áˆşđ?‘„đ?‘„đ?‘›đ?‘›Í´ áˆť Necessary

Essential

Calculation of flow velocity necessary Problems withNot reference to unsteadyNecessary flow

Duration of change from unsteady Hours Minutes Calculation of pressure gradient Non-essential Essential flow to steady flow Problems with reference to unsteady flow Volume of gas accumulated in Necessary Not necessary Duration of network change from unsteady Hours Minutes flow to steady flow Volume of gas accumulated in network

Necessary

Not necessary

đ?‘§đ?‘§ ŕľŒ Íł Low

Approximation Îť đ?‘§đ?‘§ ŕľŒ Íł đ?‘?đ?‘?Íł − đ?‘?đ?‘?Í´ ŕľŒ đ?‘“đ?‘“áˆşđ?‘„đ?‘„đ?‘›đ?‘›Í´ áˆť

Approximation Îť

đ?‘?đ?‘?Íł − đ?‘?đ?‘?Í´ ŕľŒ đ?‘“đ?‘“áˆşđ?‘„đ?‘„đ?‘›đ?‘›Í´ áˆť Necessary

Essential

Necessary

Seconds Essential Not necessary Seconds Not necessary

Tab. 2 Selected differences in mathematical models for low, medium and high pressure

Wojciec

il Prices

Wojciech Panek

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Simulation of a gas network Wojciech Panek

** AGH University of Science and Technology ÞÞPoland wojciech2panek@gmail.com

At present in Małopolska the number of consumers of high-methane gas is increasing. This gas is supplied by Polska Spółka Gazownictwa Sp.z o.o. With the growth of the number of new clients arises the question as to whether in some sections of the gas distribution network the pressure won’t fall under the safety level, and will the customers have gas? This kind of doubts emerge especially in autumn and winter because the drop in temperature automatically increases the consumption of the blue energy. In such situations it is necessary to perform static simulation of the gas network. In order to perform this task, engineers use computer softwares such as SimNet, or SONET software. The last one uses the engine of the GASNET program.

The difference in maximum work pressure of pipelines determines hallmarks in the mathematical models of simulations which describe the real system using equations.

A static simulation of gas networks includes defining the parameters of the network (diameters and length of every section of pipeline, the roughness of pipes, materials used, working pressure), and customers (the amount of gas which they use according to the tariff, ordered capacity or real capacity), defining the parameters of the gas source in the simulated section of the gas-pipeline, and, finally, choosing the best mathematical model to be used in a given simulation. The gas flow in a high-pressure network is characterized by a slow flow dynamic;

variables, which describe the system in that case, are the functions of time and it is necessary to use the dynamic models of simulations in the form of differential equations. In the low-pressure network, the flow is characterized by fast changes of velocity and pressure. This fact causes in practice some reductions in calculationsused by adopting the static models of simulation in the form of nonlinear algebraic equations. The results provide useful information about real pressure in each part of the network, flow amount, velocity, and flow resistance.

Using this data we can: ◀◀ Evaluate the consequences of adding new customers ◀◀ Evaluate the consequences of closing selected sections of pipeline, for example, for renovation ◀◀ Evaluate the consequences of increasing the gas pressure in the source ◀◀ Evaluate if the gas distribution fulfills the norms ◀◀ Determine the maximum amount of gas which can be sent via given gas-pipeline ◀◀ Analyze new investment plans aimed at improving the quality of distributing the gas ◀◀ Illustrate the after-effects of any sort of malfunction Average municipal customers receive gas from low-pressure or medium-pressure networks in which profile of flows impose the use of a static model of simulation. For the simulation to be reliable, it is necessary to have a large database which includes all the sections of the gas-pipeline, the infrastructure of the networks, and their parameters. Moreover, the database should include information about customers, and their consumption of gas.

The main advantage of static simulations of gas networks is without a doubt the possibility to adapt the network easily by changing characteristics, or

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Simulation of a gas network

its shape in a short time, as well as quickness of selecting the most suitable data, and simulating as many variants of calculations as possible. The

biggest disadvantage is the fact that precision of such computations depends on the compatibility of the data entered into the program, and should represent the actual state as closely as possible.

How does it work? – A quick presentation about the practical use of static simulations of a gasHow does itit work? work? – A quick presentation about the practical use of static simulations of a gasnetwork.

How does network.

A quick presentation about the practical use of static simulations of a gas-network.

Fig. 1 - The scheme for simulation gas network - pressure (program SONET) Fig. 1 - The scheme for simulation gas network - pressure (program SONET) Fig.1 The scheme for simulation gas network – pressure (program SONET)

Fig. 2 - The scheme of simulation for a gas network – terminal velocity (program SONET) Fig. 2 - The scheme of simulation for a gas network – terminal velocity (program SONET) Fig. 2 The scheme of simulation for a gas network – terminal velocity (program SONET)

Wojciec

network

In the presented scenario, the subject gas network is supplied from the West side, however, gas In the presented scenario, the subject gas network is supplied from the West side, however, distribution andgas safe Wojciech Panek is not effective. Not every customer has access to the source within suitable 11 and safe distribution is not effective.

Not every customer has access to the source within suitable levels of pressure (fig. 1). This is due to the high gas velocity in the section which supplies the area. It levels pressurein(fig.

1).resistance This is dueand to the high gas velocity in the2). section area. It to leads to of a growth flow a drop in pressure (fig.

One which of thesupplies possiblethe solutions leads to a growth in flow resistance and a drop in pressure (fig.

2).

One of the possible solutions to this kind of problem could be to provide a new gas source from the North.

In theof presented scenario, gas network supplied fromfrom the West however, gas distribution is this kind problem couldthe besubject to provide a newisgas source the side, North.

not effective. Not every customer has access to the source within suitable and safe levels of pressure (fig. 1).

This is due to the high gas velocity in the section which supplies the area. It leads to a growth in flow resistance and a drop in pressure (fig. 2). One of the possible solutions to this kind of problem could be to provide a new gas source from the North.

Fig. 3 - Scheme of simulated gas network – pressure with an additional source from the North

Fig. 3 - Scheme of simulated gas network – pressure with an additional source from the North Fig.3 SONET) Scheme of simulated gas network – pressure with an additional source from the (program (program SONET) North (program SONET))

Fig. 4 - Scheme of simulated gas network – terminal velocity with an additional source from the Fig. 4 Scheme of simulated gas network – terminal velocity with an additional source North (program Fig. 4 - Scheme of SONET) simulated gas network – terminal velocity with an additional source from the from the North (program SONET)

North (program When the newSONET) source is added to the network, the gas pressure increases to the volume that is required for providing the highest quality services. Also, the terminal velocity of the gas decreases, as

When the new source is added to the network, the gas pressure increases to the volume that is well as the flow resistance. The direction of flow doesn’t change. Thanks to the gas-network required for providing the highest quality services. Also, the terminal velocity of the gas decreases, as well as the flow resistance. The direction of flow doesn’t change. Thanks to the gas-network SPRING/ 2017

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simulating software, we are able to find answers for many questions as to the network decreases, in the case of connecting a new customer with the Simulation of a gas network

Athanas

In conclusion, I would like to thank Mr Piotr Narloch, Network Simulation a symbols: fromthePolskaExplanation Spółka Gazownictwa Sp. z o.o. for his assistance, and pa Explanation ofofsymbols: When the new source is added toExpert the network, gas pressure increases to the volume that is required for providing the highest quality services. Also, the terminal velocity of the gas decreases, as well as the flow resistance. The direction of flow doesn’t change. Thanks to the gas-network simulating software, we are able to find answers for many questions as to what level the pressure in the network decreases, in the case of connecting a new customer with theof symbols: Explanation appointed capacity.

In conclusion, I would like to thank Mr Piotr Narloch, Network Simulation and Balancing Senior Expert from Polska Spółka Gazownictwa Sp. z o.o. for his assistance, and patience.

References:

References •

- ‘‘Obliczanie Sieci Gazowych przegląd programó Krzysztof Bytnar, Kraków 2007

[1] Obliczanie Sieci Gazowych przegląd programów komputerowych, Tom II, Krzysztof Kogut, Krzysztof Bytnar, Kraków 2007.

• - ‘‘Realizacja zadao operatora dystrybucyjnego w [2] Realizacja zadań operatora dystrybucyjnego w zakresie bezpieczeństwa dostaw gazu na przykładzie odbiorców przykładzie odbiorców miasta Krakowa przy wyk miasta Krakowa przy wykorzystaniu symulacji statycznej sieci gazowej, Andrzej Dymacz, Piotr Narloch, Instal 10/2008.

Andrzej Dymacz, Piotr Narloch’’, Instal 10/2008 References [3]Symulacja statyczna sieci gazowej miasta Chełmna, Andrzej J. Osiadacz, Maciej Chaczykowski, Łukasz Kotyński, Teresa Zwiewka.

• - ‘’Symulacja statyczna sieci gazowej miasta Cheł • - ‘‘Obliczanie SieciGrzegorz Gazowych przegląd programów komputerowych [4]Upraszczanie schematów sieci przesyłowych, Andrzej J. Osiadacz, Dobrut, Nowoczesne GazowChaczykowski, Łukasz Kotyoski, Teresa Zwiewka nictwo, 01.10.2005r.

Krzysztof Bytnar, Kraków 2007 [5] Sterowanie pracą sieci gazowej w oparciu o dobór parametrów wyjściowych stacji gazowych, Paweł Zardze• - ‘’Upraszczanie schematów sieci przesyłowych’’ wiały, Kraków 2015r.

• - ‘‘Realizacja zadao operatora dystrybucyjnego w zakresie bezpiecze Nowoczesne Gazownictwo, [6] Metody symulacji statycznej sieci gazowej, Marta Gawron, Zeszyty Naukowe – Uniwersytet Zielonogórski.01.10.2005r. przykładzie odbiorców miasta Krakowa przy wykorzystaniu symulac Inżynieria Środowiska. 1895-7323. Z. 144, nr 24 (2011), s. 40–47.

Andrzej Dymacz, Narloch’’, Instal • Piotr - ‘’Sterowanie pracą 10/2008 sieci gazowej w oparciu o do

• •

gazowych’’, Paweł Zardzewiały, Kraków 2015r.

- ‘’Symulacja statyczna sieci gazowej miasta Chełmna’’, Andrzej J. O Chaczykowski, •Łukasz Kotyoski, Teresa Zwiewka - „Metody symulacji statycznej sieci gazowej”, M

Uniwersytet Zielonogórski. Inżynieria Środowiska - ‘’Upraszczanie schematów sieci przesyłowych’’, Andrzej J. Osiadac Nowoczesne Gazownictwo, 01.10.2005r.

•

- ‘’Sterowanie pracą sieci gazowej w oparciu o dobór parametrów w gazowych’’, Paweł Zardzewiały, Kraków 2015r.

•

- „Metody symulacji statycznej sieci gazowej”, Marta Gawron, Zeszy Uniwersytet Zielonogórski. Inżynieria Środowiska. 1895-7323. Z. 14

network

Athanasios Pitatzis

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UK Energy Sector, Current Risks and Future Challenges Athanasios Pitatzis

** ÞÞ Greece thanospitatzis@hotmail.com  University  Country  E-mail

UK Energy Sector, Current Risks and Future Challenges

Brexit would probably have several effects in the  Athanasios Pitatzis energy sector of the Great Britain, but not irreversible.

As far as the European energy security  thanospitatzis@hotmail.com is concerned,  Greeceit is believed that despite Brexit the cooperation between the United Kingdom Brexit would probably have several effects in the energy sector of the Great Britain, (UK) and the European Union (EU) will debut not irreversible. As far as the European energy security is concerned, it is believed epen because of their interdependence. Also, we that despite Brexit the cooperation between the United Kingdom (UK) and the want to emphasise that despite Brexit, the UK European Union (EU) will deepen because of their interdependence. Also, we want to will choose to remain member of the European emphasise that despite Brexit, the UK will choose to remain member of the European Energy Union perhaps following the Norwegian Energy Union perhaps following the Norwegian or Swiss model. or Swiss model.

European Energy Security, Brexit and UK growing energy dependence on imports

European Energy Security, Brexit and UK growing energy dependence on imports

UK Inland Energy Consumption (2014, % share), Source: UK Unplugged? The Impacts of

Brexit Energy and Climate Policy Report, Fig.1 UK on inland energy consumption, 2014 By (%Antony share) Froggatt, Thomas Raines and Shane Tomlinson, Chatham House, May 2016, https://www.chathamhouse.org

As we can see from the above chart, the energy mix of the Great Britain is based mainly on fossil fuels and more specifically: SPRING/ 2017   

34% in oil 34.1% in Natural Gas 16.4% in Lignite / Coal

UK Energy Sector, Current Risks and Future Challenges

14

Athanas

UK Inland Energy Consumption (2014, % share), Source: UK Unplugged? The Impacts of Brexit on Energy and Climate Policy Report, By Antony Froggatt, Thomas Raines and Shane Tomlinson, Chatham House, May 2016, https://www.chathamhouse.org

◀◀ Replace coal with natural gas, which can be imported in the form of liquefied natural gas - LNG from various sources, such as the US. The introduction of LNG form is advantageous because it is expected to average global LNG prices on the level of approximately 4–8 $ / BBtu until 2025, because there is an oversupply of the US and AuAs we can see from the above chart, the energy mix stralia. Thanks to this strategy, the country and its of the Great Britain is based mainly on fossil fuels environmental objectives may turn out successful. and more specifically: ◀◀ Increasing the role of nuclear power and renewable energy sources in the future energy mix an oversupply of the US Australia.

Thanks to this theand country ◀◀ 34% in oil ◀◀ and Open up new areas in the UK,strategy, European and its environmental objectives may turn out successful. ◀◀ 34.1% in Natural Gas foreign companies for the exploration and pro Increasing the role of nuclear power and renewable energy sources in the ◀◀ 16.4% in Lignite / Coal duction of hydrocarbons in the UK Exclusive future energy mix ◀◀ 7.2% in Nuclear Energy  Open up new areas inEconomic the UK, Zone.

European and foreign companies for the ◀◀ 7.4% on Renewable Energy Sources and and production It is also evident from the figures thatEconomic the exploration of hydrocarbons in following the UK Exclusive ◀◀ 0.9% of electricity imports from Great Britain needs the European Union Energy Zone. neighbouring countries to secure its energy needs in collaboration with its It is also evident from the following figures that the Great Britain needs the European neighbours, mainly Norway, France and Union Energy to secure its European energy needs in collaboration with its European Three future energy strategies for the United Kingthe Netherlands. neighbours, mainly Norway, France and the Netherlands. dom after Brexit would be to:

Fig. 2 Major UK imports of gas and electricity, 2014; UK– Europe gas/ electricity interconnection UK Gas and Electricity Imports for the year 2014, Source: UK Unplugged? The Impacts of Brexit on Energy and Climate Policy Report, By Antony Froggatt, Thomas Raines and Shane Tomlinson, Chatham House, May 2016, https://www.chathamhouse.org

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allenges

Athanasios Pitatzis

15

UK Gas and Electricity Imports for the year Furthermore, it is evident that the UK, like the EU, 2014, Source: UK Unplugged? The Impacts of is dependent on massive hydrocarbon imports. Of Brexit on Energy and Climate Policy Report, course, it is remarkable to note that the UK is the By Antony Froggatt, Thomas Raines and Shalargest oil producer the second of the states Furthermore, it is evident that the UK, like the EU, isanddependent on28massive ne Tomlinson, Chatham House, May 2016, (27 after Brexit) gas producer in the EU. hydrocarbon imports. Of course, it is remarkable to note that the UK is the largest oil https://www.chathamhouse.org producer and the second of the 28 states (27 after Brexit) gas producer in the EU .

Fossil Fuels Dependency of the UK and the EU, Source: UK Unplugged? The Impacts of Brexit on Energy and Climate Policy Report, By Antony Froggatt, Thomas Raines and Shane Fig.3 Import dependency of theHouse, UK andMay the EU Tomlinson, Chatham 2016, https://www.chathamhouse.org

According to the diagram above, the UK energy dependens:  In about 40% on oil consumption Dependency the UKgas andconsumption the Risks and for the UK Energy Sector over the Fossil INFuels about 45% on of natural EU, Source: UK Unplugged? The Impacts of upcoming years  In about 90% on Coal consumption.

Brexit on Energy and Climate Policy Report,

By for Antony Thomas Sector Raines and Sha-the upcoming ◀◀ Brexit andyears its impact on the UK Energy Sector Risks theFroggatt, UK Energy over ne Tomlinson, Chatham House, May 2016,

◀◀ Will the European Investment Bank continue

https://www.chathamhouse.org Brexit and its impact on the UK Energy Sectorenergy projects in the UK after Brexit? to support  Will the European Investment Bank continue support energy projects in the Accordingto to the below graph, from 2011 until UK after Brexit?

According to the below graph, from 2011 until 2015 According to the diagram above, the UK 2015 EIB invested in the UK 29,1 billion euros, EIB invested in the UK 29,1 billion euros, 28% of investments these investments were in the energy dependens: 28% of these were in the energy sector energy sector of the UK (see the graphofbelow) the UK (see the graph below) ◀◀ In about 40% on oil consumption ◀◀ In about 45% on natural gas consumption and ◀◀ In about 90% on Coal consumption.

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2



In about 90% on Coal consumption.

Risks for the UK Energy Sector over the upcoming years  

16

Brexit and its impact on the UK Energy Sector Will the European Investment Bank continue to support energy projects in the UK Energy Sector, Risks and UK after Brexit? According to the below graph, fromCurrent 2011 until 2015Future EIB Challenges invested in the UK 29,1 billion euros, 28% of these investments were in the energy sector of the UK (see the graph below)

2

EIB Lending in the UK, 2011 to 2015, Source: Brexit: future funding from the European Investment Bank? https://secondreading.uk/economy/ brexit-future-funding-from-the-european-investment-bank/ ◀◀ Limited new human capital for the UK energy companies due to new immigration law by the UK government after Brexit ◀◀ Uncertain UK Energy Regulatory Environment over the years of negotiations between the UK and the rest of the EU (possibly new changes in the status of electricity and gas interconnectors with France, the Netherlands and Ireland and energy trading) ◀◀ Decreasing domestic oil and gas production, especially if the UK bans permanently domestic shale gas production in the future ◀◀ According to the UK government the three major identified risks/case studies over UK Gas Market are: 1. Infrastructure failure 2. Freezing weather and infrastructure failure 3. Geopolitical events

◀◀ According to the International Index of Energy Security Risk 2016 Edition, the UK energy security ranking is decreasing (from 1st in 2005 to 6nd in 2016) ◀◀ Increasing government intervention and energy subsidies can reduce/damage the UK Energy Sector Competitiveness ◀◀ Closing off the UK Coal Power plants until 2025 can increase the probability of increasing the UK wholesale gas and electricity prices Our analysis indicates that the biggest risk for the UK Energy Sector is to become excluded from the European Internal Energy Market after the Brexit negotiations. Many of the risks for the UK Energy Sector (especially after Brexit) which are indicated in this analysis are confirmed by the National Grid of the UK in a recent article by Reuters.

Brexit and Future Challenges for the UK Energy Sector According to Chatham House Report the UK Energy Sector will face many problems which will depend on to the trade model of cooperation the

Athanas

allenges

Athanasios Pitatzis

UK will have after the Brexit negotiations with the European Union start, some of the uncertainties/ possibilities can be:

17

Furthermore, after Brexit UK could follow one of the following trade models with the EU regarding energy, these models are:

Furthermore, after Brexit UK could follow one of the following trade models with the The degreeenergy, of accessthese to themodels Europeanare: gas and ◀◀ The Norwegian Model EU◀◀regarding

electricity markets; ◀◀ The Energy Union model Norwegian ◀◀TheThe extent to which theModel UK would lose the capa◀◀ The Swiss Model  toThe Energy Union modelon energy pocity influence EU decision-making ◀◀ Free Trade Agreement with EU – licies, aboutSwiss wich it Model would gain sovereign regarding Canadian Model  The power to design distinct national energy policies; No trade deal with the EU - Model according  Free Trade Agreement with EU – Canadian◀◀Model ◀◀TheNo easetrade with which a deal might be negotiated to the Trade Organization deal with the EU - Model according to World the World Trade Organization with other EU states and institutions.

Tab. 1 Summary of Brexit vs Remain models Summary of Brexit vs Remain Trade Models, Source: UK Unplugged? The Impacts of Brexit on Energy and Climate Policy Report, By Antony Froggatt, Thomas Raines and Shane Tomlinson, Chatham House, May 2016, https://www.chathamhouse.org

It is evident from our analysis that the challenges for the UK Energy Sector will be: 

The future trade model between the UK and the European Union

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18 Summary of Brexit vs Remain Trade Models, Source: UK Unplugged? The Impacts of Brexit on Energy and Climate Policy Report, By Antony Froggatt, Thomas Raines and Shane Tomlinson, Chatham House, May 2016, https://www.chathamhouse.org

UK Energy Sector, Current Risks and Future Challenges

It is evident from our analysis that the challenges for the UK Energy Sector will be:

◀◀ The future shale gas domestic development in the UK ◀◀ The increasing dependence on energy imports ◀◀ In which type of renewables should the UK Energy Sector invest more money and develop? ◀◀ In which new renewable energy technologies the UK Energy companies should focus their R&D innovation?

◀◀ The future trade model between the UK and the European Union ◀◀ The future UK Energy Mix regarding the UK Energy Security (Gas and Nuclear vs Renewables and Energy Storage)

The current risks and future challenges for the UK Energy Sector is a dynamic process, so the overall results of our analysis can change rapidly in the near future due to unpredicted geopolitical, economical, political, social or technological factors.

References: [1] Brexit: future funding from the European Investment Bank? https://secondreading.uk/economy/brexit-future-funding-from-the-european-investment-bank/ [2] International Index of Energy Security Risk 2016 Edition, Institute for 21st Century Energy, http://www. energyxxi.org/sites/default/files/energyrisk_intl_2016.pdf [3] UK Unplugged? The Impacts of Brexit on Energy and Climate Policy Report, Chatham House, https:// www.chathamhouse.org/sites/files/chathamhouse/publications/research/2016-05-26-uk-unplugged-brexit-energy-froggatt-raines-tomlinson.pdf [4] Country Analysis Brief: United Kingdom, U.S Energy Information Administration (EIA), https://www. eia.gov/beta/international/analysis_includes/countries_long/United_Kingdom/uk.pdf [5] National Grid warns of costs if Britain exits EU energy market, Reuters, 20/01/2017, http://in.reuters. com/article/britain-eu-energy-costs-idINL5N1FA35V

Alex Za

allenges

Alex Zakrzewski

¡¡

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Paris Agreement: Yes We Can? Alex Zakrzewski ** Queens Mary University ÞÞ Poland alexzakrzewski@gmail.com  University  Country  E-mail

On November 4th, the Paris Agreement within the United Nations Framework Convention on Climate Change (UNFCCC) went into effect.

It is a big commitment of over 193 UNFCCC members that have signed the treaty to deal with greenhouse gases emissions. France’s foreign minister Laurent Fabius described this treaty as “ambitious and balanced”, however, many specialists are still worried about the feasibility of this important plan. There are three main aims of the convention presented in Article 2 of the document, which reads as follows: Article 2 1) This Agreement, in enhancing the implementation of the Convention, including its objective, aims to strengthen the global response to the threat of climate change, in the context of sustainable development and efforts to eradicate poverty, including by: ◀◀ Holding the increase in the global average temperature to well below 2 °C above pre-industrial levels and to pursue efforts to limit the temperature increase to 1.5 °C above pre-industrial levels, recognizing that this would significantly reduce the risks and impacts of climate change; ◀◀ Increasing the ability to adapt to the adverse impacts of climate change and foster climate resilience and low greenhouse gas emissions development, in a manner that does not threaten food production; 1 http://unfccc.int/resource/docs/2015/cop21/eng/l09r01.pdf

◀◀ Making finance flows consistent with a pathway towards low greenhouse gas emissions and climateresilient development.

2 This Agreement will be implemented to reflect equity and the principle of common but differentiated responsibilities and respective capabilities, in the light of different national circumstances. 1 This is reportedly the first time in the history that the governments have agreed on temperature rises limits. Moreover, this agreement is an outcome of around 20 years of international negotiations on this topic. However, despite this enormous effort made by politicians, many negative or sceptical voices can be heard, many among environmental organisations. Most of them criticise the agreement by saying that this “deal” is not enough to keep our planet safe and will probably miss the target of keeping global average temperature below 2 °C above pre-industrial levels. This contrasts with officials’ point of view: UN’s climate chief and foreign minister of Morocco – Patricia Espinosa, and Salaheddine Mezouar have said that: “Humanity will look back on 4 November 2016 as the day that countries of the world shut the door on inevitable climate disaster and set off with determination towards a sustainable future.

The Paris agreement is undoubtedly a turning point in the history of common human endeavour, capturing the combined political, economic and social will of governments, cities, regions and businesses and investors to overcome the existential threat of unchecked climate change.2 There is no doubt that this agreement is a step in the right direction, however, it is still not decided whether officials are too optimistic, environmentalists are too pessimistic or the truth lies in the middle. To finish this dispute, it would be useful

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economic and social will of governments, cities, regions and businesses and investors to overcome the existential threat of unchecked climate change.”2 There is no doubt that this agreement is a step in the right direction, however, it is still not decided whether officials are too optimistic, environmentalists are too pessimistic or the Paris Agreement: Yes We Can? truth20 lies in the middle. To finish this dispute, it would be useful to quote some objective data:

World CO2 emissions vs. Paris Agreement vs. IEA 450 scenario

Fig. 1 - WEO 2015. NDC emissions profile post 2030 WM assumption3 Fig. 1 WEO 2015. NDC emissions profile post 2030 WM assumption3

world CO2 emissions overlap with the Paris Agreement curve which shows that this target,

graphprepared prepared Wood we approach isinnocomparison doubt transformation must even though hard to by reach, isMackenzie stillMackenzie a realistic to IEA 450 Agreement scenario.

FromFrom thethe graph by Wood we There can clearly seethat thathuge the Paris can clearly see that the Paris Agreement scenario take place to reduce carbon footprint, however, scenario is most likely to miss the 2 °C mark represented by the IEA 450 scenario and the is most likely to miss the 2 °C mark represented by predictions show that some sectors of economy difference in targeted CO2 emissions is probably going to increase. On the other hand,

the IEA 450 scenario and the difference in targeted should change more than others. IEA-International CO2 emissions is probably going to increase. On Energy Agency has clearly outlined the impact on 2 https://www.theguardian.com/environment/2016/nov/04/paris-climate-changethe other hand, world CO2 emissions overlap with specific sectorsto under the so called 2DS scenario, There is no doubt that huge transformation must take place reduce carbon footprint, the Paris Agreement curve which shows that this which aims to reach the 2 °C mark: agreement-enters-into-force however, predictions show that some sectors of economy should change more than others.

3 target, even though hard to reach, is stillhas a realistic https://www.woodmac.com/media-centre/12533877 IEA-International Energy Agency clearly outlined the impact on specific sectors under approach in comparison to IEA 450 scenario. the so called 2DS scenario, which aims to reach the 2 °C mark:

Fig. 2 – Energy-related CO2 emissions by sector under the 2DS 2 https://www.theguardian.com/environment/2016/nov/04/parisFig. 1 Energy-related CO2 According to the above figure the biggest changes will have to be faced by power industry, -climate-change-agreement-enters-into-force emissions by sector under which is dominated by coal and gas power plants, which generate 63% of today’s global 3 https://www.woodmac.com/media-centre/12533877 the 2DS electricity.

Moreover, they are responsible for over 1/3 of energy sector greenhouse gases

emissions. Industry and transport should undergo significant transformations as well as follow??? these predictions. The introduction of hybrids and electric means of transportation should significantly decrease transport sector’s carbon footprint, however, industry must follow. IEA states that the main ways of tackling the problem is the combination of use of renewables, increased energy efficiency and CCS-carbon capture and storage.

Alex Za

We Can?

Alex Zakrzewski

21

According to the above figure the biggest changes will have to be faced by power industry, which is dominated by coal and gas power plants, which generate 63% of today’s global electricity. Moreover, they are responsible for over 1/3 of energy sector greenhouse gases emissions. Industry and transport should undergo significant transformations as well as follow??? these predictions. The introduction of hybrids and electric means of transportation should significantly decrease transport sector’s carbon footprint, however, industry must follow. IEA states that the main ways of tackling the problem is the combination of use of renewables, increased energy efficiency and CCS-carbon capture and storage.

Developed markets will find the carbon reduction goals more challenging as they have already implemented several emission-cutting policies. Wood Mackenzie research director Paul McConnell is very optimistic about China and expects that it will beat their 60% CO2 cut by around 10% in 2030.

Similarly India’s target of around 35% cut should also be easily achievable.

What does it mean for oil and gas industry? Paradoxically, IEA states that gas-fired power generation will continue to flourish up till 2040 with India and China being the most important investors. However, after 2050 if no technology advancements will have been made to this form of power generation it will be gradually declining. Previously mentioned CCS technology could be one of the important factors that could save gas-powered power plants, however, more improvements should be made to keep gas as a low-carbon option for power generation. Unfortunately, there are no good news for oil industry which will probably have a gradually decreasing impact on power generation unless any cutting-edge technologies reducing carbon dioxide emissions are to be implemented.

“The timing of a transition to low-carbon energy will be critical. Diversifying to renewable energy will be a balancing act. Moving too quickly could leave money on the table from the Majors’ fossil fuels business. But too slowly, and they could miss their window of opportunity. The biggest risk for oil and gas companies is to do nothing, and be left exposed to investors making their own minds up.

There is notably an emergence of three different strategies by the major oil companies – decarbonise, capitalise or grow. The Majors are testing different strategies to decarbonise and mitigate risks, to capitalise by using existing capabilities to explore opportunities in renewables and to grow a profitable and substantial renewables business.

Regardless of the diverging strategies, the Majors are all increasing their share in gas while also aiming to push down the cost curve. Global carbon risks could depress oil prices for the long term with slowing demand and an increase in costs, making it crucial for the Majors to push break-evens down further. To facilitate the move to low-carbon energy policies, new skills will be needed through joint ventures or acquisitions.”

IEA has specified general goals that should be followed, however, not every economy can equally implement such drastic changes. That is why the Paris Agreement is better than 450 or 2DS scenario because it takes into consideration the division between the emerging markets like China, India and the developed markets, mostly western Europe.

This transition will most likely rely heavily on renewables, therefore, any Oil&Gas enterprise will have to take some action in order to survive the upcoming years. A good analysis of the situation is presented by Paul McConnell:

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capabilities to explore opportunities in renewables and to grow a profitable and substantial renewables business. Regardless of the diverging strategies, the Majors are all increasing their share in gas while also aiming to push down the cost curve. Global carbon risks could depress oil prices for the long term with slowing demand and an increase in costs, making it crucial for the Majors to push break-evens down further. To facilitate the move to lowParis Agreement: Yes We Can? 22 carbon energy policies, new skills will be needed through joint ventures or acquisitions."

Fig. 3 – Global demand shifting to lower-carbon Fig.1 Global demand shifting to lower-carbon Conclusions can be drawn that the future of oil industry is a big question mark as the peak demand will probably be reached in the upcoming years, however, a brighter future awaits the gas industry, which is more environmentally friendly option in energy sector. Energy efficiency and new technologies could potentially slow down the transition process into low-carbon solutions, however, it will

most likely only cushion the impact on the petroleum industry. The Paris Agreement is a major step forward which is probably still not enough to completely avoid the negative impact of greenhouse effect, however, it is also more realistic approach and can be considered more seriously by all the nations and should be an important impulse to work on further advancements in CO2 reductions.

References: [1] http://www.iea.org/publications/freepublications/publication/ECCE2016.pdf.

[2] https://www.woodmac.com/analysis/Paris-agreement-ratified.

[3] http://www.rigzone.com/news/oil_gas/a/147289/Technological_Improvements_Required_For_ Gas_To_Remain_LongTerm_Fuel.

[4] https://en.wikipedia.org/wiki/Paris_Agreement#Aims.

[5] http://unfccc.int/resource/docs/2015/cop21/eng/l09r01.pdf.

[6] https://www.woodmac.com/media-centre/12533989.

[7] https://www.woodmac.com/analysis/Paris-agreement-ratified.

Aditya P

We Can?

Aditya Prabha, Kartik Mangwani, Manpreet Singh

¡¡

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Introduction to Snake Wells with Particular Focus on Rotatory Steerable System Aditya Prabha, Kartik Mangwani, Manpreet Singh

** University of Petroleum and Energy Studies, Dehradun ÞÞ India prabhaaditya37@gmail.com, karik_ mangwani@yahoo.in, manpreets975@gmail. com  University  Country  E-mail

The snake well drill is a path-breaking technology that permits us to extract oil from the previously inaccessible places. In contrast with conventional drills, advanced software grants the snake well drill to trail intricate horizontal paths, cutting through shale and sand to reach a number of diverse reservoir pockets from a single drilling platform. Snake Wells use a blend of technologies comprising extended reach drilling, swellable wellbore packers and remotely operated zonal isolation and control. Swellable wellbore packer is a segregation device that depends on elastomers to swell and form an annular seal when immersed in certain wellbore fluids.

The directional drilling technique consents the The Champion West field was discovered in 1975 and titled Champion West in 1990. It is positioned approximately 90 km offshore from Syria, 7 km N-NW of the Champion Main field and certain 10 km NE of the Iron Duke Field (Fig 1). Water depth is about 40-47m. It is 12 km X 3 km, with depths ranging between 2,000 – 4,000 m. Reservoir pressures span from 200 to 600 bar, with temperature varying from 80 to120°C. It entails extremely stratified/laminated reservoirs with unreliable fluid

path of the well to be rapt to achieve contact with as many potentially producing features as possible. This results in a ‘snake-like’ well path which intertwines up and down through multiple geological features in order to accomplish utmost reservoir drainage. It uses mobile drilling units which dodges dismantling and reassembling drilling equipment for each pad, making the process swifter and conserving resources.

Furthermore, snake wells encompass advanced directional drilling practices viz. steerable drill bits and software that generates comprehensive models of underground geology. This enables drillers to hit production targets that are less than 2 m across and miles below the surface. The pipe that maneuvers oil drills is supple enough to snake around to reach secluded pockets or follow a reservoir that meanders across the terrain.

This is a comprehensive study which ushers diverse technologies incorporated in Snake wells with a distinct emphasis on Rotatory Steerable System utilized in mobile drilling units which proliferates well connectivity and in turn enhances production. fill; constricted, stretched out fault blocks; and thin oil rims (10-100m) with intensive compartmentalization.

With good reservoir quality and an average permeability of about 200 mD and porosity of about 18percent, the fluid circulation within the field is exceedingly intricate. Generally, shallower reservoirs are oil-filled, deeper reservoirs are usually gas-filled, although some do show small oil rims. In

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gas-filled, although some do show small oil rims. In spite of log and data from the prevailing appraisal wells, ambiguities about contacts reservoirs. Pressures in the shallower reservoirs are usually hydros deep gas reservoirs are immensely overpressured. Since faults iso blocks, large aquifers are uncommon, but water within a fault block restricted water drive. Solution gas drive and some limited gas cap predominant in most Focus oil reservoirs.

Introduction to Snake Wells with Particular on Rotatory Steerable System Aditya P

spite of log and MDT pressure data from the prevailing appraisal wells, ambiguities about contacts remain in many reservoirs. Pressures in the shallower reservoirs are usually hydrostatic, whereas the deep gas reservoirs are immensely overpressured.

Since faults isolate individual blocks, large aquifers are uncommon, but water within a fault block can provide restricted water drive. Solution gas drive and some limited gas cap drive are predominant in most oil reservoirs.

Fig. 1 Location of Brunel Darussalam&Champion West Field

Conventional Approach

Conventional Approach

The most fundamental tactics is to drill vertical wells (Fig. 2a). The first wells drilled in Champion West were originally vertical. It leads to low recovery factors (and/or requires a high infill density) and has a high probability of water or gas coning.

The most fundamental tactics is to drill vertical wells (Fig. 2a). The Champion West were originally vertical. It leads to low recovery fac requires a high infill density) and has a high Fig. probability of water or g 2a

Deviated wells (Fig. 2b) depict an improved drainage efficiency, but do still need a high infill density and thus tends to a high development cost. There is a number of deviated oil producers in Champion West.

Due to high structural dip and thin stratification, horizontal wells (Fig. 2c) have similar drainage efficiency as deviated wells. They still offer single drainage point per sand. Multilaterals can increase the number of drainage points, however, they would require absolute pressure isolation back from the junction due to high structural dip, which makes it both intricate and expensive.

Snake Wells Snake wells are laterally weaving extended-reach horizontal wells that drain numerous vertically stacked, structurally dipping reservoirs. This fashions multiple drainage points in each sand and productively achieves a similar drainage pattern to a multilateral well at a fraction of the cost and technical complexity. It is symbolized as a horizontal sinusoidal pattern penetrating through the sequential layers of shale and sands packages within the reservoir for at least twice or maximum thrice

Fig. 2a Fig. 2a Fig. 2a

Fig. 2b

Fig. 2b

Deviated wells (Fig. 2b) depict an improved drainage efficiency, but d Fig. 2b high infill density and thus tends to a high development cost. There is Fig. 2b oil deviated producers Champion West. drainage efficiency, but do s Deviated wells (Fig. 2b)indepict an improved high infill density and 2b) thusdepict tendsan to improved a high development cost. There a Deviated wells (Fig. drainage efficiency, butisdo deviated producers in Champion West. high infilloil density and thus tends to a high development cost. There is a deviated oil producers in Champion West. Fig. 2c

Fig. 2c

Due Fig. to 2chigh structural dip and thin stratification, horizontal wells (Fig. 2 drainage Fig. 2c efficiency as deviated wells. They still offer single drainage p Due to high structural dip and thin stratification, horizontal wells (Fig. 2c Multilaterals can increase the number of drainage points, however, th Due to high structural dip and thin stratification, horizontal (Fig.po 2c drainage efficiency as deviated wells.

They still offer single wells drainage drainage efficiency as deviated wells. of They still offer single drainage po Multilaterals can increase the number drainage points, however, they Multilaterals can increase the number of drainage points, however, the

System

Aditya Prabha, Kartik Mangwani, Manpreet Singh

(Fig 3). This concept was primarily articulated for marginal reservoirs in Rasau, BSP and later, applied in Iron Duke as the first snake well in Brunei.

The snake provides enhanced drainage area and is equivalent to at least 3-4 short horizontal wells and thus, increases the complete ultimate recovery of the reservoirs. It surpasses the development concept of multi-laterals and multi-selective fault scoopers wells in the view of unit technical cost (UTC), recovery factors (RF), success probability and its completion robustness.

Limitations ◀◀ The potential to exit target zones at inflection points with geological and survey ambiguities while ‘snaking’ through the horizontal sections. ◀◀ Real time interpretations – reversed sections and non-unique log response produces risks of becoming stratigraphically lost. ◀◀ Vagueness of the oil columns, i.e. fluid fills. ◀◀ Hole and mud conditions – impairment/wash-outs of the horizontal sections. ◀◀ Initial well clean-up and pressure drop across the very long horizontal section ◀◀ Unfriendly water zones or early gas breakthrough.

Applied Technologies Extended Reach Drilling Extended Reach Drilling (ERD) is a cohesive method for drilling high‐angle well bores with long horizontal displacements. ERD wells are usually kicked off from the vertical adjacent to the surface and built to an angle of inclination that licenses adequate horizontal displacement from the surface to the anticipated target. This inclination is retained until the wellbore achieves the zone of interest and is then kicked off near the horizontal and stretched into the reservoir. It enables optimization of field development via the decrement of drilling sites and structures, and facilitates the operator to reach reservoir segments at a much greater distance compared to conventional directional drilling technology.

a multilateral well at a fraction of the cost and technical complexity. It as a horizontal sinusoidal pattern penetrating through the sequential l and sands packages within the reservoir for at least twice or maximum This concept was primarily articulated for marginal reservoirs in Rasa later, applied in Iron Duke as the first snake well in Brunei. The snake enhanced drainage area and is equivalent to at least 3-4 short horizo thus, increases the complete ultimate recovery of the reservoirs. It su Applied Technologies 25 development concept of multi-laterals and multi-selective fault scoope Extended Reach Drilling view of unit technical cost (UTC), recovery factors (RF), success prob Extended Reach Drilling (ERD) is a cohesive method for drillin completion robustness.

bores with long horizontal displacements. ERD wells are usua vertical adjacent to the surface and built to an angle of inclina adequate horizontal displacement from the surface to the anti inclination is retained until the wellbore achieves the zone of in kicked off near the horizontal and stretched into the reservoir. of field development via the decrement of drilling sites and str the operator to reach reservoir segments at a much greater di conventional directional drilling technology.

Applied Technologies

Extended Reach Drilling Extended Reach Drilling (ERD) is a cohesive method for drilling hig bores with long horizontal displacements. ERD wells are usually kic vertical adjacent to the surface and built to an angle of inclination th adequate horizontal displacement from the surface to the anticipate inclination is retained until the wellbore achieves the zone of interes kicked off near the horizontal and stretched into the reservoir. It ena Limitations of field development via the decrement of drilling sites and structure Fig. Fig.34 reservoir segments at a points much with greater distanc • the Theoperator potentialtotoreach exit target zones at inflection geological conventional directional drilling technology. ambiguities while „snaking‟ through the horizontal sections.

Exploitation of ERD procedures in: • 1.

Real time interpretations reversed sections andnow non-unique re Developing offshore –reservoirs which are deemedlog une produces risks of becoming 2. Drilling under shippingstratigraphically lanes or underlost. environmentally delic • 3.

Vagueness of theproduction oil columns,byi.e. fluid fills.

Accelerating drilling long divisions of almost h • producing Hole and mud conditions – impairment/wash-outs of the horizontal s formations.

• Initial well clean-up and pressure drop across the very long horizont 4. Providing a substitute for some subsea completions.

• Unfriendly water zones or early gas breakthrough.

5. Reduction of the number of platforms essential to develop a

Mobile Drilling Units Conventional underground mobile drilling units have usually b drilling the snake wells in the Champion West field with satisfa repercussions achieving the drilling objective within the time li Fig. 4 pioneering model for underground drilling of snake wells has b Fig. 4 herewith.

Exploitation of ERD procedures in:

1. Developing offshore reservoirs which are now deemed uneconom 2. Drilling under shipping lanes or under environmentally delicate ar 3. Accelerating production by drilling long divisions of almost horizo producing formations.

4. Providing a substitute for some subsea completions.

5. Reduction of the number of platforms essential to develop a large

Mobile Drilling Units Conventional underground mobile drilling units have usually been e drilling the snake wells in the Champion West field with satisfactory 5 the time limit. H repercussions achieving the drilling objective Fig. within pioneering model for underground drilling of snake wells has been p herewith.

Fig. 5

Fig. 5

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Introduction to Snake Wells with Particular Focus on Rotatory Steerable System

Exploitation of ERD procedures in: ◀◀ 1. Developing offshore reservoirs which are now deemed uneconomical. ◀◀ 2. Drilling under shipping lanes or under environmentally delicate areas. ◀◀ 3. Accelerating production by drilling long divisions of almost horizontal holes in producing formations. ◀◀ 4. Providing a substitute for some subsea completions. ◀◀ 5. Reduction of the number of platforms essential to develop a large reservoir.

Mobile Drilling Units Conventional underground mobile drilling units have usually been employed while drilling the snake wells in the Champion West field with satisfactory performance and repercussions achieving the drilling objective within the time limit. However, a pioneering model for underground drilling of snake wells has been proposed herewith.

A subterrene is an underground travelling vehicle moving forward either by mechanical drilling, or by melting. These are portrayed as cylindrical in shape with conical drill heads at one or both ends, with a tank-sort-of body for propulsion, and labelled either as departing with an empty tunnel behind, or as plugging the space behind it with debris. A subterrene working thermally, utilizes high temperature and immense pressure to melt and push through rock. The apex is equipped with a stationary drill tip which is kept at 1,300–1,700 °F (700–930 °C).

The molten rock is pressed around the edges as the vehicle is driven forward, and cools to a glass-like lining of the tunnel. Enormous amount of energy is requisite to heat the drill head, delivered by nuclear power or electricity.

Rotatory Steerable System A Rotary Steerable System (RSS) is a drilling technology principally applied in underground mobile drilling units functioned in extended reach drilling.

It uses specialized downhole equipment to swap conventional mud motors. They are programmed by the Measurement while drilling (MWD) engineer who conveys commands through surface equipment characteristically using either pressure fluctuations in the mud column or disparities in the drill string rotation whichever the tool responds to, and progressively steers into the preferred direction. It, in turn, eliminates the need to „slide” a mud motor.

The current RSS works on the principal of three autonomous hydraulic pads mounted 120° apart in a non-rotating steering unit. Each pad is directed by hydraulic oil stored in an accumulator and is counteracted to wellbore pressure. Hydraulic oil used for pad extension and retraction is regulated using direct functioning solenoid valves. The extension of each pad is attained through an accurate position measurement device to deliver feedback to the controller.

Figure 6 illustrates the principal of control system operation. The system is competent to overgauge borehole situations since each pad has one inch of travel. This assists the control unit to maintain contact in hole-sizes up to 9.7 in. for the 8 ½-in.-hole-size option and 9.9 in. for the 8 ¾-in.-hole-size option.

Design Upgrade Specification for Higher-Dogleg RSS for Snake wells ◀◀ Nominal Tool Size: 6 ¾ in. ◀◀ Hole Size: 8 ½ in. and 8 ¾ in. ◀◀ Planned Dogleg Capability: Planned up to 10°/100 ft. ◀◀ Maximum Dogleg Capability: 12°–14°/100ft capability in gauge hole ◀◀ Maximum Tool Diameter: 7 ¾ in. at Steering Unit ◀◀ Flow Rate: 250 to 700 Gallons per minute ◀◀ Maximum Hydrostatic Pressure: 22,000 psi ◀◀ Maximum Temperature: 150°C (302°F) ◀◀ Maximum Rotary Speed: 250 RPM ◀◀ Maximum Weight on bit: 45,000 lbs. ◀◀ Maximum Torque: 20,000 ft-lbs

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System

Onboard Measurements: Caliper7, Inclination and Gamma eliminates the need to "slide" a mud motor.

The current RSS works on the principal of three autonomous hydraulic pads mounted The current RSS has already fitted most of the operational s 120° apart in a non-rotating steering unit. Each pad is challenges directed by hydraulic oil stored the system to deliver 12°-14°/1 were to upgrade in an accumulator and is counteracted to wellbore pressure. Hydraulic oil used for tolerate rotating through 10°/100ft curves for e pad extension and retraction is regulated using direct mechanically functioning solenoid valves. the system 3-point geometry was appraised using in-house The extension of each pad is attained through an accurate position measurement software had been developed, tested and upgraded based o device to deliver feedback to the controller.

Aditya Prabha, Kartik Mangwani, Manpreet Singh 27 6 ¾-in. RSS comm Figure 6 illustrates the principal of control system operation.

The system is operating the existing accumulated while competent to overgauge borehole situations since each pad has one inch of travel. blueprint for probable dogleg fundamentally required optimiz This assists the control unit to maintain contact in hole-sizes up to 9.7 in. for the 8 ½bit-to-steering unit and steering unit-to-3rd touch stabilizer. in.-hole-size option and 9.9 in. for the 8 ¾-in.-hole-size option.

Fig. 6 Fig. 6 Fig.77 Fig. Design Upgrade Specification for Higher-Dogleg RSS for Snake wells It shows the critical areas that required upgrade.

Nominal Tool Size: 6 ¾ in.

Hole Size: 8 ½ in. and 8 ¾ in.

For optimization of spacing between the 3rd touch points, an ◀ ◀ Downhole Life: 250 hours operating Planned Dogleg Capability: Planned up to 10°/100 ft. allocated for an overall tool length decrement. The necessary, which made the bit box vital to the driveshaft an ◀◀ Bit Pressure No restriction upper sleeve Maximum DoglegDrop: Capability: 12°-14°/100ft capability in gauge hole stabilizer was intended to be integral

◀◀ Positive Displacement Motor Power: PDM Powered option with real-time short-hop for underpowered rigs ◀◀ Onboard Measurements: Caliper7, Inclination and Gamma The current RSS has already fitted most of the operational specification. The main challenges were to upgrade the system to deliver 12°–14°/100ft build rates and mechanically tolerate rotating through 10°/100ft curves for extensive periods. For this the system 3-point geometry was appraised using in-house prediction software. This software had been developed, tested and upgraded based on several years of data accumulated while operating the existing 6 ¾-in. RSS commercially. The upgraded blueprint for probable dogleg fundamentally required optimizing the spacing between bit-to-steering unit and steering unit-to-3rd touch stabilizer. It shows the critical areas that required upgrade.

For optimization of spacing between the 3rd touch points, an upgraded driveshaft was necessary, which made the bit box vital to the driveshaft and also

overall tool length decrement. The upper sleeve stabilizer w to the upper end sub, which reduced the distance to to the upper end sub, which reduced the distance to the 3rd the 3rd touch point.

Drilling Test Facilities & Results

Drilling Test Facilities & were Resultsconducted operating the RSS in Full-scale drilling tests compressive strength formations with a water-gel mud syste Full-scale drilling tests8were conducted operating engineered in both ½-in. and 8-¾ in. hole sizes to compar the RSS in 5,000 – 25,000 PSI compressive strength Compact) bit desi Numerous PDC (Polycrystalline Diamond formationsthe witheffect a water-gel mud system.

Testsand werestructure with boreh measure of gauge length engineeredand in both 8 ½-in. and 8-¾ hole sizes of wellbores drilled capability consistency.

Thein.majority cement plugs close toresults. vertical. to compare directional Numerous PDC Test results for Diamond vertical Compact) drilling are shown in Tab. 1. The tes (Polycrystalline bit designs thewere RSS set into Automated Vertical evaluated measure the effect of gaugeMode8 length through interbedd sequences Smith quality, MDi616 (2-in. passive gauge). As c and structurewith withaborehole dogleg capability and consistency. The majority of wellbores drilled were sidetracked from cement plugs close to vertical.

Test results for vertical drilling are shown in Tab. 1. The tests were carried out with the RSS set in Automated Vertical Mode8 through interbedded sand and shale sequences with a Smith MDi616 (2in. passive gauge). As can be seen from the surveys, the inclination was quickly dropped from 0.44° to 0.09° and maintained below 0.1°.

SPRING/ 2017

surveys, the inclination was quickly dropped from 0.44° to 0.09° and maint below 0.1°.

Tab. and toRSS with 8Focus ½-in.

SmithSteerable MDi616 (2-in. pasP Aditya Introduction Snake settings Wells with Particular on Rotatory System 28 1 Survey data gauge) - Vertical Section

test if the system could overcome the build trend. The surveys indicate that on lowside toolface/0.05-in. offset the system responded well dropping inclination. The offset was then increased to 0.35 in. to assess higher drop rate. At 87% of maximum offset, the RSS produced 12°/100ft drop rate. While using the same bit that drilled the curve, it was critical that the system was well-balanced and controllable while drilling the lateral. There was no gain in having a system that was very effective at drilling The most crucial area of the drilling tests was toRSS attain high and consistent the most curve but was to control This has a very The crucial area ofdifficult the drilling tests was in to the lateral. the survey dataparticular and RSS settings with 8 ½-in.

Smith through curve. were ultimately attain high andthe consistent doglegs through the MDi616 passive from kick-off, gradu- the attention neutral tendency when theNumerous steering unit isbits central in(2-in. theapplied hole. gauge) Thisbut tendency makes curve.

Numerous bits were applied but ultimately ally staging up the offset to 75% of its maximum. the system very efficient in the lateral requiring very little work to maintain inclination having a system that could generate good results with a passive gauge bit the attention on down having on a system could Depth Once the build direction was authenticated, the or move upwas and Truethat Vertical (TVD).

enhanced hole and Tab.exceptional 2 shows thecontrol survey generate good results with aquality passive gauge bit forstability. tool displayed toolface with data and RS Tab. 3 -hole Survey data and RSS settings with the 8 ½-in.

Smith MDi616 -target.

75% of Maximum enhanced quality and stability.

Tab. 2 shows effective toolface (TF) on with 8 ½-in. Smith MDi616 (2-in. passive gauge) from kick-off, gradually st Offset and Fine Control

the offset to 75% of its maximum. Once the build direction was authentica Tab.1 Survey data and RSS displayed exceptional toolface control with the effective toolface (TF) on ta settings with 8 ½-in. Smith MDi616 (2-in. passive

Tab. 2 - Survey data and RSS settings with 8 ½-in. Smith MDi616 (2-in. pa gauge) – Vertical Section gauge) - Kick-Off and Build Rate Tests Tab.2 Survey data and RSS settings with 8 ½-in. Smith MDi616 – 75% of Maximum Offset and Fine Control

Tab.3 Survey data and RSS settings with 8 ½-in. Smith MDi616 (2-in. passive gauge) – Lateral Control

Tab.4 shows 3 depicts the survey datadrilling using the same bitRSS at was higher Tab. test results obtained while a lateral well. The set ininclination with automated steering mode (Hold Mode) where control Target Inclination can be altered It was also critic maximum offset and finer dogleg on lower offsets. quickly and accurately using a non-intrusive Flow/RPM downlink method. Few high-build rates couldmay be be reduced and drilling become manageable changes in Target Inclination required while the lateral to keep the for a soft land well in the sweet spot as per geologist‟s instructions.

Downlinks to trim the Target that the RSS landing point adjustment on approach. The results specified Inclination can be done while drilling if required, thus reducing non-productive time. of producing more thansettings 10°/100ft buildSmith rateMDi616 when(2-in. on passive highside toolface/0.30 Tab. 4 - Survey data and RSS with 8 ½-in.

As dem gauge) – Lateral setting.

This Control is 75% of maximum offset capability in 8 ½-in. hole size,target whic(

The sy the system with fine potential for overgauge borehole situations. Effective lateral back-calculated from the surveys were within 10° or less from the setit still toolfm

enhanced hole quality and stability. Tab. 2 shows the survey data and RSS s with 8 ½-in. Smith MDi616 (2-in. passive gauge) from kick-off, gradually stag the offset to 75% of its maximum. Once the build direction was authenticated displayed exceptional toolface control with the effective toolface (TF) on targ System

Aditya Prabha, Kartik Mangwani, Manpreet Singh

29 Tab. 2 - Survey data and RSS settings with 8 ½-in. Smith MDi616 (2-in. pass gauge) - Kick-Off and Build Rate Tests Tab.4 Survey data and RSS settings with 8 ½-in. Smith MDi616 (2-in. passive gauge) – Kick-Off and Build Rate Tests

Tab. 3 depicts the survey data using the same bit at higher inclination with 7 maximum offset and finer dogleg control on lower offsets. was The most crucial area of the drilling testsItwas to at- also critical tain high and consistent doglegs through the curve. high-build rates could be reduced and become manageable for a soft landing Numerous bits were applied but ultimately the atlanding point adjustment on approach. specified that the RSS is tentionThe was onresults having a system that could generate of producing more than 10°/100ft build ratewith when on highside toolface/0.30-i good results a passive gauge bit for enhanced hole quality and stability.

Tab. 2 shows the survey setting. This is 75% of maximum offset capability in 8 ½-in. hole size, which d data and RSS settings with 8 ½-in. Smith MDi616 the system with fine potential for overgauge borehole situations.

(2-in. passive gauge) from kick-off, gradually sta- Effective too ging upwithin the offset to10° 75% ofor its maximum.

Once the back-calculated from the surveys were less from the set toolfac build direction was authenticated, the tool displaywas very good control and essential for high-dogleg applications. The results ed exceptional toolface control with the effective highlight that the system reduced build highside offs toolfacerate (TF) on on target. test if the toolface/0.05-in. system could overcome the buildThe trend.toolface The surveys indicate provide a controlled approach for soft landing. was then set low that on lowside toolface/0.05-in. offset the system responded well dropping inclination. The offset was then increased to 0.35 in. to assess higher drop rate. At 87% of maximum offset, the RSS produced 12°/100ft drop rate. While using the same bit that drilled the curve, it was critical that the system was well-balanced and controllable while drilling the lateral. There was no gain in having a system that was very effective at drilling the curve but was difficult to control in the lateral. This particular RSS has a very neutral tendency when the steering unit is central in the hole. This tendency makes the system very efficient in the lateral requiring very little work to maintain inclination or move up and down on True Vertical Depth (TVD).

Tab. 4 shows test results obtained while drilling a lateral well. The RSS was set in automated steering mode (Hold Mode) where Target Inclination can

As demonstrated in Tab. 4, the TVD was controlled within ±0.05 ft (±0.6 in.) to the target (6185.1 ft TVD) in the 2340-ft (from 7543 ft. to 9883 ft. MD) horizontal section.

SPRING/ 2017 The system attested to have enough delicacy to produce marginal doglegs along the lateral section. Even though the well was drilled adjacent to the upper transition zone, it still managed to sustain predictable control. This tendency is accredited to the

30

Introduction to Snake Wells with Particular Focus on Rotatory Steerable System

Aditya P

be altered quickly and accurately using a non-intrusive Flow/RPM downlink method. Few changes in Target Inclination may be required while drilling the lateral to keep the well in the sweet spot as per geologist’s instructions. Downlinks to trim the Target Inclination can be done while drilling if required, thus reducing non-productive time.

As demonstrated in Tab. 4, the TVD was controlled within ±0.05 ft (±0.6 in.) to the target (6185.1 ft TVD) in the 2340-ft (from 7543 ft. to 9883 ft.

MD) horizontal section. The system attested to have enough delicacy to produce marginal doglegs along the lateral section. Even though the well was drilled adjacent to the upper transition zone, it still managed to sustain predictable control. This tendency is accredited to the neutral behavior of the assembly when on zero offset. This particular RSS has good stability and no strong directional tendencies when the steering unit is centralized in the hole. This neutral feature ultimately leads to higher-quality hole as the system is only making very small steering unit changes to build and drop at low-dogleg values.

A summary of the results obtained is condensed in a plot of build rate versus offset shown in Fig. 8. The results produced a close to linear relation, which is perfect for high-, medium- and low-dogleg applications. The 6 ¾-in. high-dogleg RSS is capable of producing up to 0.5-in. offset in 8 ¾-in. hole.

This build rate was considered more than enough to buttress a planned maximum build rate, even in overgauged, low-quality hole conditions. Overall test results were very positive.

Pioneering Evolutions

A new high build-up rate (HBR) rotary-steerable drilling system (RSS) with comprehensive logging-while-drilling (LWD) capabilities was developed and commercialized. The new HBR RSS was designed to provide extensive LWD services, including propagation and deep resistivity, neutron and density porosity measurements, borehole imaging and many others at build-up rates up to 12°/100 ft. Using closed-loop control and a short

Fig. 8 - The pure build-up test result with high-dogleg RSS in 8 ¾-i Fig. 8 The pure build-up test result with high-doglegEvolutions RSS in 8 ¾-in. hole Pioneering A new high build-up rate (HBR) rotary-steerable drilling system (RS comprehensive logging-while-drilling (LWD) capabilities was devel commercialized. The new HBR RSS was designed to provide exte steering sleeve that decouples steering functionality services, including propagation and deep resistivity, neutron and d from drilling dynamics, theimaging system can measurements, borehole andperform many others at build-up rate open-hole sidetracks and drill high severity sleeve that decoupl Using closed-loop control and a dogleg short steering (DLS) curves anddrilling laterals dynamics, in one run with functionality from theprecise system can perform open-h drilldirectional high dogleg severity (DLS) curveswithout and laterals in one run with control and well placement, control and the wellfatigue placement, the fatigue limits of exceeding limits of without the LWDexceeding tools.

Introduction to RSS Operating Principles

The new HBR RSS can be considered a hybrid system because it Introduction to RSS Operating Principles “point the bit” and “push the bit” modes, depending on the instant r wellbore trajectory. When instigating a change to the wellbore traje The new HBR RSS cantobethe considered hybrid sysimmediately pushed side byathe extendable pads located on tem because it operatesprimarily with “point andthe bit” mode. After dr sleeve, thus operating in the the bit” “push bit” modes, on the instantis utilized to bend the b the“push new the curvature, thedepending steering mechanism requirements of the trajectory.

When in-effectually “point the b assembly (BHA) intowellbore the new curvature and to stigating be steered, thus a principally a change tooperating the wellboreintrajectory, the bit“point the bit” notion (F theisnew HBR RSS systems steer immediately pushed to the side by by the“floating” extenda- between the theoret pointing and pushing the bit.

It enables HBR RSS system to be ble pads located on the non-rotating sleeve,the thus positive facets of each principle, and to avoid operating primarily in the “push the bit” mode. their specific disadva HBR RSS systems are of more agile than pure After drilling a few feet the new curvature, the “point” systems, rende borehole quality than “push” systems and steer more dependably a steering mechanism is utilized to bend the bottom wider range of formation types than other systems. hole assembly (BHA) into the new curvature and effectually “point the bit” in the direction to be steered, thus operating in a principally “point the bit” notion (Fig. 9). As such, the new HBR RSS systems steer by “floating” between the theoretical extremes of pointing and pushing the bit. It enables the HBR RSS system to benefit from the positive facets of each principle, and to avoid their specific disadvantages. The new HBR RSS systems are more agile than pure “point” systems, rendering higher borehole quality than “push” systems and steer more dependably and predictably in a wider range of formation types than other systems.

System

Aditya Prabha, Kartik Mangwani, Manpreet Singh

31

Conventional RSS vs. HBR RSS Conventional RSS systems utilize a sensor package, usually accelerometers, mounted close to the steering mechanism of the tool to calculate the current orientation of the RSS system. Instead, the new HBR RSS uses both accelerometers and magnetometers mounted in the rotating part of the tool, in conjunction with a Hall sensor and magnet combination to calculate the tool’s orientation. As the drillstring rotates, the magnets pass over the Hall sensor. At each crossing of the Hall sensor, a synchronizing signal is sent from the Hall sensor to the control electronics in the steering unit where an algorithm combines this signal with the sensor readings from the accelerometer and magnetometer package to calculate the orientation of Rib 1. The design changes included support for various modes of operation to increase the application range not only in high build-up rate, but also in challenging vertical wellbore applications. In addition to the standard gravity-steer mode, the new steering unit can use the magnetic-steer mode. The magnetic sensor package is positioned in the primary electronics, so the HBR RSS can now reliably kick off from vertical in the desired azimuthal direction, without the previous requirement to build angle at an uncertain azimuth and then correct it if necessary. Increased strength, durability and functionality were other design-change focus criteria. Major improvements were introduced to increase overall reliability, such as: ◀◀ Stronger drive shaft ◀◀ Improved mud-bearing design ◀◀ Integrated, non-magnetic stabilizer in the steering unit ◀◀ Integrated vibration and stick-slip sensors in the steering unit that support real-time drilling optimization in any BHA configuration.

Reduction of Wellbore Tortuosity Wellbore tortuosity can be well-defined as any undesirable deviation from the planned well trajectory or in short well complexity in horizontal wells.

Tortuosity is a latent source of surplus torque/drag and can lead to complications while running casing,

incorporated into the well and start to swell when coming in co wellbore fluids, with the usual fluids of choice being water- or packers swell, they seal off the annulus between the liner/casi to provide segregation between zones with varying p Fig.wellbore 9 flow in the annulus and avert migration of fines along the wellb Fig. 9 Conventional RSS vs. HBR fracturing and stimulation provideRSS an easy method of breaking Conventional RSSwithout systems utilize a sensor usuallybya smaller sectors increasing the costpackage, and complexity mounted to the steering mechanism of the tool to calcula cementclose and perforating methods. orientation of the RSS system. Instead, the new HBR RSS use and magnetometers mounted in the rotating part of the tool, in sensor and magnet combination to calculate the tool‟s orientat rotates, the magnets pass over the Hall sensor. At each crossi a synchronizing signal is sent from the Hall sensor to the contr steering unit where an algorithm combines this signal with the the accelerometer and magnetometer package to calculate the The design changes included support for various modes of ope application range not only in high build-up rate, but also in cha wellbore applications. In addition to the standard gravity-steer steering unit can use the magnetic-steer mode. The magnetic positioned in the primary electronics, so the HBR RSS can now vertical in the desired azimuthal direction, without the previous angle at an uncertain azimuth and then correct it if necessary.

Fig. 10and functionality were other design-change focus crit durability Fig. 10 improvements were introduced to increase overall reliability, su Zonal isolation is important as communication can result in de ● Stronger drive shaft fluids injected into unwanted zones, inadequate stimulation of ● Improved mud-bearing design leakage of fluids along the annulus, sand formation, gas migra ● Integrated, non-magnetic stabilizer in the steering unit operations. ● Integrated vibration In and stick-slip sensors liners and completions. explicit applications, ex- in the steering uni Advantages drilling optimization in any BHA tortuosity in rigs horizontal wells configuration. can even cur•cessive Small-footprint (offshore).

Reduction ofzones Tortuosity productivity.

ItWellbore has been claimed and eventually •tail Horizontal where cementing is not beneficial.

Wellbore tortuosity can be well-defined any undesirable dev •proved Lateral zones where compartmental isolation is prerequisite. that rotary steerable systems facilitate a as less planned trajectory or in short well complexity in horizontal •tortuous Heftywell permeability variation. wellbore. latent source of surplus • Water-flood shut-off.torque/drag and can lead to complicati •Reactive Debris barrier applications. In explicit applications, excessi casing, liners and completions.

Element Packers horizontal wells can even curtail productivity. It has been claim Conclusions proved that rotary steerable systems facilitate a less tortuous w Reactive elementwells packers (REPs), often referredextended reach horiz 1. Snake laterally weaving Reactive Elementare Packers numerous structurally dipping reserv to as swelling packers,vertically deliver anstacked, elegant solution Reactive element packers (REPs), often referred to as swelling a horizontal sinusoidal patternThese penetrating through the for multiple-zone open-hole completions. elegant solution for multiple-zone open-hole completions. Thes shale and sands packages within packers are incorporated into the well and start tothe reservoir for twice providing drainage points. swell when coming inmultiple contact with several wellbore 2. ERD is used for drilling high‐angle well bores with long displacements. It enables optimization of field developm decrement of drilling sites and structures, and ensures sectors at greater SPRING/ 2017 distance.

3. The concept of incorporating a Subterrene while drilling been proposed as a potential idea which necessitates f mobile it will avert the lethargy of dismantling and reass equipment.

32

Introduction to Snake Wells with Particular Focus on Rotatory Steerable System

fluids, with the usual fluids of choice being wateror oil-based fluids. As the packers swell, they seal off the annulus between the liner/casing and the open-hole wellbore to provide segregation between zones with varying pressures, or to shut off flow in the annulus and avert migration of fines along the wellbore. REPs utilized for fracturing and stimulation provide an easy method of breaking the desired zone into smaller sectors without increasing the cost and complexity by using the traditional cement and perforating methods.

Zonal isolation is important as communication can result in decrease in productivity, fluids injected into unwanted zones, inadequate stimulation of intended zones, leakage of fluids along the annulus, sand formation, gas migration and costly curative operations.

Advantages ◀◀ Small-footprint rigs (offshore). ◀◀ Horizontal zones where cementing is not beneficial. ◀◀ Lateral zones where compartmental isolation is prerequisite. ◀◀ Hefty permeability variation. ◀◀ Water-flood shut-off. ◀◀ Debris barrier applications.

2.

3.

4.

5.

Conclusions 1. Snake wells are laterally weaving extended reach horizontal wells draining numerous vertically stacked, structurally dipping reservoirs. It is symbolized as a horizontal sinusoidal pattern penetrating through the sequential layers of shale and sands packages within the reservoir

6.

for twice or maximum thrice providing multiple drainage points.

ERD is used for drilling high‐angle well bores with long horizontal displacements. It enables optimization of field development through decrement of drilling sites and structures, and ensures reaching reservoir sectors at greater distance.

The concept of incorporating a Subterrene while drilling of Snake wells has been proposed as a potential idea which necessitates further research. Being mobile it will avert the lethargy of dismantling and reassembling of drilling equipment.

A Rotary Steerable System (RSS) is a drilling technology predominantly applied in underground mobile drilling units functioned in extended reach drilling. Requisite up gradation of RSS assembly in drilling of vertical, deviated and lateral wells have been demonstrated after researching through various papers. A new high build-up rate (HBR) rotary-steerable drilling system (RSS) with comprehensive logging-while-drilling (LWD) capabilities has been introduced and it operates with both “point the bit” and “push the bit” modes.

Wellbore tortuosity can be defined as undesirable deviation or well complexity in horizontal wells. The curtailment of wellbore tortuosity is one of the greatest advantage of RSS. Reactive Element Packers or Swellable Wellbore Packers provides zonal isolation, which is critical, as lack of it can result in decrease in productivity, fluids injected into unwanted zones, inadequate stimulation of intended zones, sand production and gas migration.

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References [1] W. Obendrauf, K. Schrader, N. Al-Farsi, and A. White, Smart Snake Wells in Champion West- Expected and Unexpected benefits from Smart Completions, SPE, Brunei Shell Petroleum Co. Sdn. Bhd. 2006.

[2] Aidiradiman Haji Johan, SPE, Brunei Shell Petroleum Company Sdn. Bhd; and Kirby Schrader, Combination of Snake Well Design & Smart Completions: Key Enablers for Champion West Development, SPE, Brunei Shell Petroleum Company Sdn. Bhd. 2004.

[3] L. Bacarreza, SPE, C. Hornabrook, Chong Chuan Khoo, Harald Nevøy, and Nor-Janiah Japar, The Snaking Wells in Champion West, Offhore Brunei- Best Practices for ERD Well Construction, Brunei Shell Petroleum Co. Sdn. Bhd. 2008.

[4] Apparatus and Method for Large Tunnel Excavation in Hard Rock. US Patent Office.1974.

[5] Sugiura, J: “The Use of the Near-bit Vibration Sensor While Drilling Leads to Optimized Rotary-Steerable Drilling in Push- and Point-the-Bit Configurations”, SPE 115572. October 2008.

[6] Sugiura, J., and Jones, S: “Integrated Approach to Rotary-Steerable Drilling Optimization Using Concurrent Real-time Measurement of Near-bit Borehole Caliper and Near-bit Vibration”, SPE 112163. February 2008.

[7] Jones, S., Sugiura, J., and Barton, S.: “Results from Systematic Rotary-Steerable Testing with PDC Drill-Bits Depicts the Optimal Balance between Stability, Steerability and Borehole Quality”, SPE 112579. March 2008.

[8] Enrico Biscaro, John David D’Alessandro, Adriana Moreno, Matthias Hahn, Raymond Lamborn,Mohammed H. Al-Naabi, and Aaron C. Bowser, New Rotary Steerable Drilling System Delivers Extensive Formation Evaluation for High Build Rate Wells, Baker Hughes. 2015.

[9] P.Weijermans, J.Ruszka, SPE, Baker Hughes INTEQ, H.Jamshidian, M.Matheson, Drilling with Rotary Steerable System Reduces Wellbore Tortuosity, Shell U.K. Expro. 2001.

[10] S. Yakeley, T. Foster, and W. Laflin, Swellable Packers for Well Fracturing and Stimulation, Baker Oil Tools. 2007.

SPRING/ 2017

Scale Formation Problems in Oil & Gas Industry: Its Reduction Procedures by Chemical Introduction

34

¡¡

Scale Formation Problems in Oil & Gas Industry: Its Reduction Procedures by Chemical Introduction Sachin Nambiar, Vivek Thakar

** Pandit Deendayal Petroleum University ÞÞ India sachinnambiar8@gmail.com  University  Country  E-mail

Oilfield scaling is serious for oil and gas industry. Every year the problem with scale costs the industry millions of dollars in damage and lost production. The scale is one of the leading cause of worldwide decline. In the North Sea area, 28% decline is related to the formation of scale.

The scale is an assemblage of deposits that clog perforations, casings, production tubings, valves, pumps and down holes, completion equipment, thereby clogging the well-bore and preventing fluid-flow. Most scales found in oil fields forms either by direct precipitation from water that occurs naturally in reservoir rocks or as a result of produced water becoming over-saturated with scale component when two incompatible glasses of water meet downhole. Whenever an oil or gas well produces water or water injection is used

to enhance recovery, there is a possibility that a scale will form. The global cost of scale is estimated at more than USD 4 billion a year. Scale control form can for some fields be the single biggest operational cost. The economic consequences of scale have been estimated to have the highest impact on North and South America.

In the upcoming years, the scale costs will increase with the reservoirs becoming mature and requiring pressure maintenance by water flooding to increase recovery. The formation of scale may occur in the reservoir, in the wellbore or in the surface facilities. Scale deposits may cause formation damage by blocking pore throats, flow restriction by blocking flow lines and tubing, completion damage by plugging perforations, screens, advanced completions, and gravel packs,choke and safety valve failure, pump wear, flow meter and instrumental failure, corrosion underneath scale deposits etc. Suspended solids can cause plugged formation, reduce oil/water separator efficiency and settlement in topside equipment. This paper is a literature review on methods of how to control scale formation using various chemicals; and its economic feasibility in the petroleum industry.

Scale Formation

Formation of scale depends on parameters such as:

Principle In a hydrocarbon reservoir, before a well is drilled and completed, the fluids in the formation are being saturated with dissolved salt. After the well is drilled the fluids no longer remain in equilibrium and salts may start to precipitate. This means that scale begins to form when such solubility limit for one or more components is exceeded.

◀◀ change in pressure and temperature ◀◀ degree of agitation/turbulence during formation of crystals ◀◀ size and number of seed crystals ◀◀ degree of super-saturation ◀◀ change in pH of solution.

Saturation Ratio for salts = [Mz+][Xz–] / Ksp

Sachin N

Heterogeneous nucleation is a process where scale crystals start to grow on substrates like metalli surfaces, sand grains or on pre-existing surface defects.

Sachin Nambiar, Vivek Thakar oduction 35

Where Mz+ and Xz- represent the salts and M being the cation with a positive charge and X is the anion with a negative charge.

The solubility product is called Ksp (equilibrium constant for the dissolution of the salt). The solubility product is a measure of how many moles of ions per unit volume of solvent there can be in a system before a salt precipitates out. If the saturation ratio equals 1.0, the solution is saturated and neither precipitation nor dissolution of salts will occur. ◀◀ When the SR is less than 1.0 the solution is under-saturated and precipitation will not occur. ◀◀ When the SR is greater than 1.0 the solution is oversaturated and precipitation of salts may occur ( SCALE FORMATION )

Heterogeneous nucleation is a process where scale crystals start to grow surfaces, sand grains or on pre-existing surface defects.

This will, however, depend on the kinetics of the precipitation reaction. Some salts do not start spontaneous precipitation even if they are hundreds times super-saturated.

Fig. 1

The produced water that goes through a pH shift, a temperature or pressure change or is in contact with incompatible water, does not always produce Processes of Scale Formation scale, even though the produced water has become oversaturated. This is because the scale must grow from solution to form. The process is called nucleation and constitutes  Incompatible mixingthe first stage in scale formation. Nucleation is the creation of a sub particle or ion cluster consisting of several individual scaling Scale from incompatible mixing occurs when two incompatible waters, like injected seawate ions. There are two different nucleation processes and formation water,nucleation get mixed downhole. The produced water then gets oversaturated wit called homogeneous and heterogeneous scale components.

This happens seawater has a high content or sulfate (SO4-2) an nucleation. Homogeneous nucleation is abecause process +2 +2 in which scale is growth a supersaturated formation water richstarts in inions such as calcium Fig. 1 (Ca ) and barium (Ba ). Mixing of these tw withprecipitation ion pairs forming of single crystals scales, in Fig. 1 as BaSO . waters solution leads to sulfate such 4 solution Heterogeneous nucleation is a process Processes of Scale Formation where scale crystals start to grow on substrates like  Evaporation metallic surfaces, sand grains or on pre-existing  Incompatible mixing surface defects

When a mixture of hydrocarbon gas and formationScale water produced simultaneous, from is incompatible mixing occurs when twoevaporation incompatible w and formation water, get mixed downhole. The produced water t induced scale may occur. A pressure drop caused by reduced hydrostatic pressure leads to a scale components. This happens because seawater has a high co expansion of the hydrocarbon gas and the hot brine phasewater evaporates. concentration wi formation is rich in ionsThe such salt as calcium (Ca+2) and barium waters leads to precipitation of sulfate scales, such as BaSO4. then increase above the solubility limit and the salt will precipitate. Halite (NaCl) scale in Hig temperature High pressure (HTHP) wells is the most common scale type to be formed this way.

Evaporation



When a mixture of hydrocarbon gas and formation water is produce induced scale may occur. A pressure drop caused by reduced hyd expansion of the hydrocarbon gas and the hot brine phase evaporate SPRING/ 2017 then increase above the solubility limit and the salt will precipitate. temperature High pressure (HTHP) wells is the most common scale

Auto-Scaling



Auto-Scaling

36

Scale Formation Problems in Oil & Gas Industry: Its Reduction Procedures by Chemical Introduction

Processes of Scale Formation ◀◀ Incompatible mixing Scale from incompatible mixing occurs when two incompatible waters, like injected seawater and formation water, get mixed downhole. The produced water then gets oversaturated with scale components. This happens because seawater has a high content or sulfate (SO4-2) and formation water is rich in ions such as calcium (Ca+2) and barium (Ba+2). Mixing of these two waters leads to precipitation of sulfate scales, such as BaSO4. ◀◀ Evaporation When a mixture of hydrocarbon gas and formation water is produced simultaneous, evaporation-induced scale may occur. A pressure drop caused by reduced hydrostatic pressure leads to an expansion of the hydrocarbon gas and the hot brine phase evaporates. The salt concentration will then increase above the solubility limit and the salt will precipitate. Halite (NaCl) scale in High temperature High pressure (HTHP) wells is the most common scale type to be formed this way. ◀◀ Auto-Scaling This occurs when the natural water in the reservoir undergoes a change in pressure and/or temperature when it is produced. Normally an increase in temperature tends to increase water solubility of a salt which implies more ions gets dissolved at high temperatures. Similarly, decrease in pressure tends to decrease water solubility.

Problems Caused by Scales The formation of scale may occur in a reservoir, in a wellbore or in the surface facilities. Scale deposits may cause ◀◀ Formation damage by blocking pore throats ◀◀ Flow restriction by blocking flow lines and tubing

◀◀ Completion damage by plugging perforations, screens, advanced completions, and gravel packs ◀◀ Choke and safety valve failure ◀◀ Pump wear ◀◀ Flow meter and instrumental failure ◀◀ Corrosion underneath scale deposits ◀◀ Suspended solids can cause ◀◀ Plugged formation ◀◀ Reduce oil/water separator efficiency ◀◀ Settlement in topside equipment

Case 1: At the surface of water injection facility where incompatible sources of water are mixed prior to injection.

Case 2: In the injection wells where the injected water starts to mix with the reservoir formation water.

Case 3: Downhole in the reservoir where the injected water displaces formation water.

Case 4: Downhole in the reservoir where the mixed injected water and formation water are about to reach the range of producing wells.

Case 5: Production tubing.

Case 6: At the connection of a branched zone where each branch produces different waters.

Case 7: At the manifold of producing zone where water is produced from different blocks within the same producing zone.

Case 8: At topside facility where produced fluids are mixed with different zones to separate oil and gas from produced waters, or in pipelines that transport produced fluids to on-shore processing facilities.

Sachin N

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Sachin Nambiar, Vivek Thakar

37

Fig. 2 Fig. 2

Case 1: At the surface of water injection facility where incompatible sources of water are mixed prior to injection.

Case 2: In the injection wells where the injected water starts to mix with the reservoir formation water.

Experiments Conducted

◀◀ After the completion of chemical experiment the

samples underwent throughwater.

XRD again and none Case 3: Downhole in the reservoir where the injected water displaces formation ◀◀ A collection of samples of casing and tubing was

or fewer peaks were obtained, which assured the

Case 4: done Downhole the reservoir where the mixed injected water

by PDPUinAlumni from ONGC Ahmedabad removal of scales.and formation water are about to Basin) wells.

• Scale inhibition is a chemical treatment used reach the(samples range of KG producing ◀◀ An analysis of samples of casing and tubing for

to control or prevent scale from forming in a producing well. Scale inhibitors are water-soSolar Department via X-Ray Diffractometer (meluble chemicals that are designed to prevent or Case 6: At the connection of a branched zone where each branch produces different waters. asuring instrument for analyzing the structure of a retard the nucleation and the crystal growth of material from the scattering pattern produced when scales.from They can reduce the rate ofwithin sca- the Case 7: At the manifold of producing zone where water inorganic is produced different blocks a beam of radiation or particles (such as X-rays or le formation to almost zero. For a scale inhibitor same producing zone. neutrons) interacts with it) to be considered as a good inhibitor it must be ◀ The analysis of the where peaks obtained wasfluids done are mixed with different zones to separate oil and gas Case 8: ◀At topside facility produced using thewaters, HIGHSCORE PLUS (comprehensive Stable:fluids It musttobeon-shore sufficientlyprocessing stable tinder facilities. the confrom produced or in pipelines that transport produced phase identification software used in XRD with ditions imposed. additional functionalities of profile fitting, crystallographic and extended cluster analysis) Compatible: It must not interfere with the action ◀◀ Casing and tubing samples were tested in the of other oilfield chemicals, nor be affected . It must chemical laboratory for the removal of scales by be compatible with the chemical injection system Experiments increasingConducted concentration of acids under operating them. ◀◀ A variation of the removal of scales with concentration of acids was also noticed and the de-scaling Efficient: It must be able to inhibit the scale in qurate was calculated. estion, irrespective of the mechanisms operating.

Case 5: the Production tubing. identification of minerals was done in PDPU

SPRING/ 2017

38

Scale Formation Problems in Oil & Gas Industry: Its Reduction Procedures by Chemical Introduction

Graph 1 Case 1: Casing 1. Effect of concentration of HNO3 on weight loss of the sample Concentration

Time (minutes)

Initial weight sample (g)

1%

60

5

2%

60

5

3%

60

5

4%

60

5%

60

Final weight sample (g)

Dissolved scale (g)

%-dissolution

Rate of de-scaling

4

1

20

0.3333

3.6

1.4

28

0.466

2.2

2.9

58

0.9666

5

1.7

3.2

64

1.066

5

0.9

4.1

82

1.366

Dissolved scale (g)

%-dissolution

Rate of de-scaling

2. Effect of concentration of Hydrochloric acid on weight loss of the sample Concentration

Time (minutes)

Initial weight sample (g)

Final weight sample (g)

1%

60

5

3

2

40

0.666

2%

60

5

2.5

2.5

50

0.833

Sachin N

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Sachin Nambiar, Vivek Thakar

39

3%

60

5

1.4

3.4

68

1.133

4%

60

5

1

4

80

1.333

5%

60

5

0.3

4.7

94

1.566

3. Effect of concentration of H2SO4 on weight loss of the sample Concentration

Time (minutes)

Initial weight sample (g)

Final weight sample (g)

Dissolved scale (g)

%-dissolution

Rate of de-scaling

1%

60

5

5

0

0

0

2%

60

5

5

0

0

0

3%

60

5

4.4

0.6

12

1.932

4%

60

5

4.5

0.5

10

0.166

5%

60

5

4.5

0.5

10

0.166

4. Effect of concentration of HCOOH on weight loss of the sample Concentration

Time (minutes)

Initial weight sample (g)

Final weight sample (g)

Dissolved scale (g)

%-dissolution

Rate of de-scaling

1%

60

5

4

1

20

0.333

2%

60

5

4

1

20

0.333

3%

60

5

3.5

1.5

30

0.5

4%

60

5

3

2

40

0.666

5%

60

5

2.7

1.3

26

0.433

5. Dissolved mass of scale in casing in different acid solution for 5g sample in 60 mins. % - dissolution

Concentration

Time (minutes)

HNO3

HCl

H2SO4

HCOOH

1%

60

1

2

0

1

2%

60

1.4

2.5

0

1

3%

60

2.9

3.4

0.5

1.5

4%

60

3.2

4

0.5

2

5%

60

4.1

4.7

0.5

2.3

SPRING/ 2017

Scale Formation Problems in Oil & Gas Industry: Its Reduction Procedures by Chemical Introduction

40

Graph 2 Case 2: Tubings Dissolved mass of scale in casing in different acid solution for 5g sample in 60 mins Concentration

Time (minutes)

% - dissolution HNO3

HCl

H2SO4

HCOOH

1%

60

0.5

1.5

0

0

2%

60

0.92

2

0

0.24

3%

60

1.4

2.9

0.2

0.76

4%

60

1.98

3.5

0.34

1.12

5%

60

2.77

4.2

0.51

1.76

Graph 3

Sachin N

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Sachin Nambiar, Vivek Thakar

41

Case 3: On an Average Scale Dissolution (%) vs Concentration of Various Acids Can Be Inferred as

Graph 4 Conclusions

Graph 3

For the prevention of scale formation in an economical manner, inorganic acids ( except H2SO4 ) proved to be more effective as compared to organic acids. HCl and HNO3 are better candidates to be used for chemical de-scaling of tubing and casing. HCl may provide 30–50% saving on circulation time as compared to HNO3 based on the rate of dissolution. XRD plots also shown great variation after chemical treatment signifying scale removal.

Fig. 4 XRD plots before and after acid treatment in CASINGS

SPRING/ 2017

42

Scale Formation Problems in Oil & Gas Industry: Its Reduction Procedures by Chemical Introduction

Fig. 5 XRD plots before and after acid treatment in TUBINGS

References [1] Femier WW and M. Ziauddin, removal and inhibition of organic scale in oilfield environment 2008.

[2] Kelund M.A Productions chemical for oil and gas Industry 2009.

[3] Norwegian Petroleum Directorate.

[4] Al. Salami, AR and AA Momen, Downhole and Topside scale challenge “Removal, prevention and inhibition technology for scales”, 2000.

[5] Crabtree, fighting scale- Removal and Prevention in Oilfield review, 1999.

[6] petrowiki.org/Scale_problems_in_production.

[7] www.kemira.com/en/industries-applications/Pages/scale-inhibition-production.aspx.

[8] Prediction of Scale Formation Problems in Oil Reservoirs and Production Equipment due to Injection of Incompatible Waters Authors J. Moghadasi, A. Sharif, H. Müuller-Steinhagen, M. Jamialahmad.

Tarun K

oduction

Tarun Kumar, Kishan Kumar Gupta, Akshita Agarwal

¡¡

43

Employing Alkaline Surfactant Polymer in Chemical Enhanced Oil Recovery Tarun Kumar, Kishan Kumar Gupta, Akshita Agarwal

** University of Petroleum & Energy Studies, Dehradun ÞÞ India tarunoberoi92@gmail.com  University  Country  E-mail

The decline in the oil and gas market has been one of the crucial points of concern since the past year. In order to meet ever increasing demands, we need to devise some newer and efficient techniques that could help recovering more oil from the declining wells, which is possible by maximizing hydrocarbon recovery factors through Enhanced Oil Recovery (EOR) processes. Alkaline Surfactant Polymer (ASP) flooding is a form of chemical enhanced oil recovery (EOR) that can allow operators to extend reservoir pool life and extract incremental reserves currently inaccessible by conventional EOR techniques such as water-flooding.

In the ASP process, surfactants are chemicals that reduce interfacial tension (IFT) between

Introduction Enhanced Oil Recovery (EOR) is a technology in which some form of additional energy input is given into a hydrocarbon reservoir in order to make more oil or gas movements towards the producer wells with an aim to enhance the ultimate total recovery from the reservoir. Since most of the reservoirs are now at matured state with low production rate thus, enhanced oil recovery (EOR) projects are strongly influenced by the current economics, type of reserve oil and crude oil price.

oil and water and extracts oil that is trapped between tiny pores of reservoir rocks. On the other hand, alkali reduces adsorption of surfactants on rock surfaces and reacts with the petroleum acids in the reservoir forming a surfactant hydroxide ion in-situ. Alkalies like NaOH, KOH etc. can be used in various concentrations and flooded for better oil recovery along with the surfactant, which forms the main agenda of this abstract. The polymer used reduces water fingering, increases sweep efficiency and decreases the amount of chemicals required as compared to that in other chemical methods. Chemical Flooding is one of the most promising EOR processes. With alkaline agents such as sodium hydroxide and silicates, surfactant concentrations as low as 0.1% can be used, which is less than 5% of the concentration used in miceller solution for miceller/polymer technology, which makes it better. This method is not only cost-effective but also more economical method, which can be used in EOR and can solve the challenges faced by the oil industry in recovery of oil from potential old/sick wells.

When secondary oil recovery proves inadequate to meet the present production rate, then tertiary recovery begins, which includes Thermal and Non-thermal or Chemical EOR. Currently, Alkaline surfactant polymer (ASP) flooding is considered the most promising chemical method in EOR because it integrates the advantages of alkali, surfactant and polymer. In the ASP process, a very low concentration of the surfactant is used to achieve ultra low Interfacial tension (IFT) between the trapped oil and the injection fluid/formation water.

The alkali also simultaneously reacts with the acidic

SPRING/ 2017

44

Employing Alkaline Surfactant Polymer in Chemical Enhanced Oil Recovery

components in the crude oil to form additional surfactant in situ, thus, continuously providing ultra low IFT and freeing the trapped oil. In the ASP

Fig. 1 – Types of eor methods

Tarun K

process, polymer is used to increase the viscosity of the injection fluid, to minimise channelling, and provide mobility control.

Fig. 1 Types of eor methods

When secondary oil recovery proves inadequate to meet the present productio Alkaline flooding ASP a veryThermal smart enhanced oil recovery process tertiary recovery begins, which includes and Non-thermal or Chemic provided the consumption is not too large.

Currently, Alkaline surfactant polymer (ASP) flooding is considered the most Alkaline chemical such as sodium hydroxide, sochemical method EORis added because Application it integrates advantages of alkali, surfac dium orthosilicate or sodiumin carbonate of alkalinethe flooding has four to injected water.

Alkaline chemicals reduce the mechanisms: polymer. In the ASP process, a very low concentration of the surfactant is use surfactant retention, increase the pH value and ◀◀ “Emulsification and Entrainment”, wherein the ultra Interfacial (IFT) flowing between the trapped also reactlow with the acidic content oftension hydrocarbons alkali entrains crude oil. oil and the injection flu (Naphthenic acids)alkali to generate more surfactants in ◀◀ “Wettability change of wettawater.

The also simultaneously reactsReversal”. withHere thetheacidic components in the the reservoir. Eventually, the surfactants play a big bility (Oil-Wet to Water-Wet) affects the change in form additional surfactant in situ, permeability, thus, continuously providing ultra low IFT a role to increase oil recovery by reducing interfacial thus increasing oil production. trapped oil.oilIn process, polymer is Reversal”. used to tension between andthe water.ASP The main objecti◀◀ “Wettability Hereincrease the change ofthe wet- viscosity of th ve of thisto method is to lower interfacial tension, and tability (Water-wet to oil-wet) control. helps to get low fluid, minimise channelling, provide mobility

Alkaline flooding of anionic surfactants that decrease costs and make changing the wettability and reducing adsorption

residual oil saturation through low IFT. ◀◀ “Emulsification and Entrapment” here the emulsified oil improves sweep efficiency.

Alkaline chemical such as sodium hydroxide, sodium orthosilicate or sodium added to injected water. Alkaline chemicals reduce the surfactant retention, in value and also react with the acidic content of hydrocarbons (Naphthenic acid more surfactants in the reservoir. Eventually, the surfactants play a big role to recovery by reducing interfacial tension between oil and water. The main obje method is to lower interfacial tension, changing the wettability and reducing a anionic surfactants that decrease costs and make ASP a very smart enhanced o

ecovery

Tarun Kumar, Kishan Kumar Gupta, Akshita Agarwal

45

Fig. 2 - Schematic of alkaline recovery proces

Fig. 2 Schematic of alkaline recovery proces

Alkali and Polymer Interaction Alkali and Polymer Interaction

alkali reacts with acids in the reservoir fluids and with carbonates rocks alkaline gets precipitated The synergy between alkali and polymer flooding may be summarized as follows: The synergy between alkali and polymer flooding as hydroxides. So surfactants are used along with  summarized Alkaliasinfollows: an alkaline-polymer alkaline solution canthereduce polymer adsorption and poly may be to reduce loss of alkali by precipitation. can reduce alkaline consumption.

Also by using only alkaline flooding process, some ◀◀ Alkali in an alkaline-polymer solution can reamount of oil is left trapped in the reservoir due  Polymer makes the alkaline-polymer solution more viscous to improve sweep duce polymer adsorption and polymer can reduce to a high capillary pressure. To get moveable oil, efficiency. Thus, polymer ―brings‖ alkaline solution to the oil zone where the a alkaline consumption. surfactant agents are introduced into the reservoir cannot go without polymer.

More oil can be displaced byinterfacial lowered IFT owing to ◀◀ Polymer makes the alkaline-polymer solution to increase oil recovery by lowering the more viscous to improve sweep Thus,words, tension between and water. Trapped droplets generated soap.efficiency.

In other alkali andoilpolymer workoil together to improve bo polymer “brings” alkaline solution to the oil zone are mobilized due to a reduction in interfacial tensweep efficiency and displacement efficiency. where the alkali cannot go without polymer. More sion between oil.

The alkaline-polymer environment may decrease biodegradation oil canbe displaced by lowered IFT owing to alkali-generated soap.

In other words, alkali andpolymer polymer A surfactantdue structure basically consists of 2salt parts:from added alkal Alkali may reduce viscosity to the increased work together to improve both sweep efficiency A hydrophilic head (water-loving) and a hydrois a negative effect. However, phobic in tight formation, this effect may help improve and displacement efficiency. tail. injectivity near the wellbore region. ◀◀ The alkaline-polymer environment may decrease biodegradation ◀◀ Alkali may reduce polymer viscosity due to the Surfactant Flooding increased salt from added alkali. This is a negative effect. However, in tight formation, this effect may Surfactant flooding iswellbore an encouraging enhanced oil recovery method. By using only alk help improve injectivity near the region.



flooding, alkali reacts with acids in the reservoir fluids and with carbonates rocks alkal Surfactant Flooding as hydroxides. So surfactants are used along with alkaline to reduce th gets precipitated of alkali by precipitation. Also by using only alkaline flooding process, some amount o Fig. 3 Surfactant flooding is an encouraging enhanced oil Fig. 3 left trapped in the reservoir due to a high capillary pressure. To get moveable oil, surfa recovery method. By using only alkaline flooding, Surfactants can be classified into four main according to the ion agents are introduced into the reservoir to increase oil recovery bycategories lowering the interfa hydrophilic head as shown in Figure 4: tension between oil and water. Trapped oil droplets are mobilized due to a reduction in interfacial tension between oil.

A surfactant structure basically consists of 2 parts: A hydrophilic head (water-loving) a SPRING/ 2017 hydrophobic tail.

46 Fig. 3

Employing Alkaline Surfactant Polymer in Chemical Enhanced Oil Recovery

Surfactants can be classified into categories four mainaccording categories Surfactants can be classified into four main to theaccording ionic chargeto of the their ionic hydrophilic headhead as shown in Figurein 4: Figure 4: hydrophilic as shown

Fig. 4 - Classification of surfactants

Tarun K

charge of the

Fig. 4 Classification of surfactants

Anionic surfactants are the most commonly-used surfactants because of their relatively low

Anionic surfactants the most commonly-u◀◀ Non-ionic: Polyoxyethylene Alcohol adsorption in are sandstone and clays, stability and relatively cheap price, eg.:lauryl sulphates sed surfactants because of their relatively low ◀◀ Zwitter-ionic/Amphoteric: Dodecyl Betaine dialkyl sulfosuccinate. They dissociate in water into an amphiphilic anion and a cation. Th adsorption in sandstone and clays, stability and ◀◀ Polymer Flooding cation is general, either an alkaline metal (Na+, K+) or a quaternary ammonium. relatively cheap price, eg.:lauryl sulphates and dialinjectedThey surfactant create IFTuses inpolymer ordersolutions to mobilize Polymer flooding which in-the residual oil an kylThe sulfosuccinate. dissociate slug in water into an ultra-low ananion oil bank in which both water flow of continuously.

The fact that oil recover creases the viscosity the displacing water, hence ancreates amphiphilic and a cation.

The cation is oil and water to oil ratio; thereby in- wettability general, an alkaline metal (Na+,reservoirs K+) or a fromeither fractured carbonate candecreasing be increased bymobility surfactant-induced creasing the oil recovery. polymer flooding, reservoirs. quaternary ammonium. alteration increases application of surfactant flooding toDuring oil-wet carbonate a water-soluble polymer is added to the injected water in order to increase water viscosity. Adding a The injected surfactant slug create an ultra-low IFT Different types of Surfactants used: water-soluble polymer to the water-flood allows the in order to mobilize the residual oil and creates an Naboth Stearate water to move through more of the reservoir rocks, oilAnionic: bank in which oil and water flow contiCationic: Cetyl bromide resulting in a larger percentage of oil recovery. nuously. The fact that oiltrimethylammonium recovery from fractured Non-ionic: Polyoxyethylene Alcohol carbonate reservoirs can be increased by surfacThere are three potential ways in which polymer tant-induced wettability alteration increases appliZwitter-ionic/Amphoteric: Dodecyl Betaine flooding makes the oil recovery process more efcation of surfactant flooding to oil-wet carbonate ficient: reservoirs. ◀◀ Different types of Surfactants used: ◀◀ Anionic: Na Stearate ◀◀ Cationic: Cetyl trimethylammonium bromide

◀◀ Through the effects of polymers on fractional flow. ◀◀ By decreasing the water/oil mobility ratio.

ecovery

• Through the effects of polymers on fractional flow. • By decreasing the water/oil mobility ratio. • By diverting injected water from zones that have been swept.

The reservoir temperature and the chemical properties of the reservoir water decide th type of polymer being used. At high temperature or with high salinity in reservoir wate Tarun Kumar, Kishan Kumar Gupta, Akshita Agarwal 47 most of its viscosit polymer cannot be kept stabile, and polymer concentration will lose

Fig. 5 After Water Flooding; After PAM Flooding

Fig. 5 – After Water Flooding; After PAM Flooding ◀◀ By diverting injected water from zones that have Polymer Types been swept.

Biopolymers – Biopolymers are derived from a fermentation process thus they have smaller molecular weight than the PAM. Its molecular structure gives Polymers are and long chainsthe formed repeating units. There are main The reservoir temperature the molecular chemical propermoleculeby great stiffness, a monomer characteristic that ties oftwo the reservoir decide the type of poly- in reduction gives the biopolymer excellent viscosifying typeswater of polymers, effective of mobility ratio: power mer being used. At high temperature or with high in high salinity water. However, they have less viscosalinity in reservoir water, the polymer cannot be sifying power than polyacrylamide in fresh waters.

Polyacrylamides (PAM): kept stabile, and polymer concentration will lose.

They have good resistance to shear degradation.

These are condensation polymers and their performance depend on the molecular weigh Also, they are not retained on the rock surface and degree hydrolyzed, some of the into acryl is replaced by Polymer Typesof hydrolysis. When partiallythus they are more easily propagated the amide forconverted into acrylic acid. This tends to increase the viscosity of fresh water but reduce mation than polyacrylamide, which can reduce the Polymers are long molecular formed by reamount ofcan polymer required for a flood. viscosity of hardchains waters.

Polyacrylamides absorb many times of its mass in water w peatingionic monomer units. There are mainly types the polymer to release some of its water. They are relativ substances like salttwocause of polymers, effective in reduction of mobility ratio: in fresh Factorswater, affecting Polymer Solution Viscosity cheap, develop good viscosities and adsorb on the rock surface to give a

term permeability reduction. The main disadvantages are their tendency to shear degrad

Polyacrylamides (PAM): The polymer viscosity is a key parameter to improve at high flow rates, and their poor performance in high salinity brine.

These are condensation polymers and their perforthe mobility ratio between oil and water. It is affecmance depend on the molecular weight and degree ted by a number of factors: Biopolymers - Biopolymers derivedaffecting from a fermentation process thus they have sm of hydrolysis.

When partially hydrolyzed, someare of Factors Polymer Solution Viscosity the acryl amide is replaced by or converted into ◀ For a given setstructure of conditions,gives solution viscosity molecular weight than the PAM. Its◀molecular the molecule great stiffn acrylic acid. This tends to increase the viscosity The polymer increasesviscosity with the increase polymer molecular isviscosifying a keyinparameter to improve the mobility characteristic that gives the biopolymer excellent power in high salinityratio wa of fresh water but reduces the viscosity of hard It is affected weight. by a number of factors: However, they have less viscosifying power polyacrylamide into fresh waters. They h given setthan of conditions, solutionleads viscosity waters. Polyacrylamides can absorb many times 1. For◀◀aIncreased concentration of polymer hi- increases with the inc good resistance to shear degradation.

Also, they are not retained on the rock surface a molecular weight. of its mass in water while ionic substances like gher viscosity and thus increased sweep efficiency.

2.

Increased concentration of polymer leads to higher viscosity and thus salt cause thethey polymer to release of its water. ◀◀ Asinto the degree of PAM increases up topolyacrylamide, a certain thus are moresome easily propagated the formation than which ca efficiency.

They are relatively cheap, develop good viscosities value, the viscosity increases. reduce the amount of polymer required for a flood. of PAM increases up to aviscosity certain value, the viscosity in in fresh water, and adsorb on the rock surface to 3. As â—€the â—€ Asdegree temperature of solution increases, 4.

As temperature of solution increases, viscosity decreases. give a long-term permeability reduction. The main decreases.

5.

Increased salinity and hardness in the water decreases the viscosity o disadvantages are their tendency to shear degrada◀◀ Increased salinity and hardness in the water detion at high flow rates, and their poor performance creases the viscosity of anionic polymers. in high salinity brine.

Fig. 6 Viscosity VS Concentration, mg/L

Fig. 6 - Viscosity VS Concentration, Mobility Control

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SPRING/ 2017

During a standard water flood sweep efficiency is lower than desired. A the water flooding into the oil bank is usually a problem. The use of Po

Fig. 6 - Viscosity VS Concentration, Mobility Control

48

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During a standard water flood sweep efficiency is lower than

TarunTh K Employing Alkaline Surfactant in Chemical Enhanced Recovery the waterPolymer flooding into the oil bank isOil usually a problem.

this fingering effect by increasing the viscosity of water.

Mobility Control During a standard water flood sweep efficiency is lower than desired. A fingering effect of the water flooding into the oil bank is usually a problem. The use of Polymer flood reduces this fingering effect by increasing the viscosity of water Alkaline-Surfactant-Polymer (ASP) Fig. 7 Fingering effect with water flooding

Alkaline surfactant flooding method comprises of injecting alkaline (NA2CO3, KOH) followed by surfactant and polymer. The main objectives of the method are to reduce the loss of surfactants by retention and changing the wettability ASP flooding uses benefits of the three flooding methods simultaneously and is recognized as a cost-effective chemical flooding process, increasing capillary number, improving mobility and enhancing microscopic displacing efficiency. Field applications of alkali flooding often result in poor recovery due to alkali loss caused by reaction with rock; low acid content of oil and lack of mobility control. However, injecting a surfactant with alkali solution has been proven to be an effective process to both alkali loss and low acid content of oil while injecting polymer with alkali/surfactant slugs considerably improves oil recovery.

Shorter time periods, and cyclic injection are much more beneficial than continuous and long period injections. Flooding is profitable when the concentration is low and injection occurs in the early years.

Injection of surfactant at a later time reduces the Interfacial tension of the fluids. Alkaline chemicals react with acidic oil components in-situ to create petroleum soap, which is one of the surfactants.

A synthetic surfactant is injected simultaneously with the alkali. A water-soluble polymer is also injected, both in mixture with the alkali and surfactant to increase the viscosity of the injectant, thereby improving mobility control of the flood fronts time might not be profitable. On the other hand, long injection period might not be profitable. So injection for 2 or 3 years can be an optimal choice.

Fig. 7 - Fingering effect with water flooding

Fig. 8 - Decreased Fingering effect with polymer flooding

Alkaline-Surfactant-Polymer (ASP) Alkaline surfactant flooding method comprises of injecting alkaline (NA2CO3, KOH) followed Fig.polymer.

8 Decreased withflooding by surfactant and The mainFingering objectives ofeffect the method are to reduce the loss of Fingering effect with polymer Fig. 8 - Decreased surfactants by retention and changing the wettability. polymer flooding

Alkaline-Surfactant-Polymer (ASP)

Alkaline surfactant flooding method comprises of injecting alkaline ( by surfactant and polymer. The main objectives of the method are to surfactants by retention and changing the wettability.

to increase the viscosity of the injectant, thereby improving mobility control of the flood fronts might notcases be profitable. On the other hand, long injection period might not be Fig. 9 - time Different ASP Fig. 9 Different ASP cases profitable. So injection for 2 or 3 years can be an optimal choice.

ASP flooding uses benefits of the three flooding methods simultaneously and is recognized as a cost-effective chemical flooding process, increasing capillary number, improving mobility and enhancing microscopic displacing efficiency. Field applications of alkali flooding often result in poor recovery due to alkali loss caused by reaction with rock; low acid content of oil and lack of mobility control. However, injecting a surfactant with alkali solution has been proven to be an effective process to both alkali loss and low acid content of oil while injecting polymer with alkali/surfactant slugs considerably improves oil recovery.

Shorter time periods, and cyclic injection are much more beneficial than continuous and long period injections. Flooding is profitable when the concentration is low and injection occurs in the early years. Injection of surfactant at a later time reduces the Interfacial tension of the fluids. Alkaline chemicals react with acidic oil components in-situ to create petroleum soap, which is one of the surfactants. A synthetic surfactant is injected simultaneously with the alkali. A water-soluble polymer is also injected, both in mixture with the alkali and surfactant

Fig. 9 - Different ASP cases

ASP flooding uses benefits of the three flooding methods simultaneo process, increasing capillary numb and enhancing microscopic displacingwith efficiency.

Field applications o Fig. 10 C-segment oil production time The injection solution viscositydue has significant recovery. aqueous phase result in poor recovery to alkalieffect lossoncaused byLower reaction with rock viscosity, i.e. higher mobility ratio, has lower oil recovery even with wide low interfacial and lack of mobility control.

However, injecting a surfactant with alk tension region. Oil will be trapped again as the low tension region moves ahead. ASP proce proven beeither an effective alkali loss and low acid con could worktowell with small process surfactantto slugboth or large dispersion. polymer with alkali/surfactant slugs considerably improves oil recove Application of Acrylic Acid Ascyclic Precipitation Inhibitor Shorter time periods, and injection are much more beneficial t period injections. Flooding is profitable when the concentration is lo It has been found that about 60% of the world‘s oil reserves and 40% of the world‘s gas the early Injection of surfactant at a later time reduces the Int reserves existyears. in carbonate rocks. Having been potentially attractive, these rocks exhibit immense variation inchemicals properties that include porosity, permeability, and flow mechanism. fluids. Alkaline react with acidic oil components in-situ to These carbonate formations exhibit large amounts of calcium and magnesium ions in form which is one of the surfactants. A synthetic surfactant is injected sim a cost-effective flooding Fig. 10 - C-segment oilchemical production with time

ecovery

Tarun Kumar, Kishan Kumar Gupta, Akshita Agarwal

The injection solution viscosity has significant effect on recovery. Lower aqueous phase viscosity, i.e. higher mobility ratio, has lower oil recovery even with wide low interfacial tension region. Oil will be trapped again as the low tension region moves ahead. ASP process could work well either with small surfactant slug or large dispersion.

Application of Acrylic Acid As Precipitation Inhibitor It has been found that about 60% of the world’s oil reserves and 40% of the world’s gas reserves exist in carbonate rocks. Having been potentially attractive, these rocks exhibit immense variation in properties that include porosity, permeability, and flow mechanism. These carbonate formations exhibit large amounts of calcium and magnesium ions in form of Calcite and Dolomite.

Economic Feasibility

49 The main limitation of ASP flooding in carbonate reservoir is the precipitation of alkali and the surfactants by these divalent minerals (such as calcium and magnesium ions). These precipitations thereby cause significant pore plugging and may damage the formation.

Using acrylic acid in combination with the ASP flooding can overcome this hurdle of hydroxide precipitation in the reservoir; by forming in-situ precipitation inhibitors. Acrylic acid has the ability to react with the sodium ions present in the brine to form sodium acrylate. The produced sodium acrylate then accumulates on the surface of the divalent cations (calcium and magnesium ions), hence prevent them from precipitating. The performance of the acrylic acid was evaluated in the presence of sodium metaborate as an alkaline, alpha olefin sulfonate as a surfactant and AN-125 SH as a polymer.

Economic Feasibility

Fig. 11 World’s ASP Projects (from oil & gas journals eor surveys) The estimate of the amount to be recovered through

in a global oil recovery combined for both, primary

meters of oil saturation, pore volume and previous primary and secondary recovery, and the actual recovery calculation differs among the techniques.

The primary recovery of oil does not exceed more than 20% and for the secondary recovery (waterflooding) of oil the incremental recovery does not exceed more than 15–25% of oil; hence resulting

of the reservoir. The Enhanced Oil Recovery techniques can recover up to 60–65% of the original oil present in the reservoir.

Projects & gas journals eor surveys) Fig. 11 - World’s EOR application is based on ASP actual reservoir para- (from andoil secondary recovery ranging between 35–45%

The estimate of the amount to be recovered through EOR application is b reservoir parameters of oil saturation, pore volume and previous primary ASP flooding technique has shown to be an ecorecovery, and the actual recovery calculation differs among nomically viable technology in comparison with the techniqu water floods. The combination of Alkaline, recovery of oil does not exceed simple more than 20% and for the secondary re flooding) of oil the incremental recovery does not exceed more than 15hence resulting in a global oil recovery combinedSPRING/ 2017 for both, primary and se ranging between 35-45% of the reservoir. The Enhanced Oil Recovery tec up to 60-65% of the original oil present in the reservoir.

50

Employing Alkaline Surfactant Polymer in Chemical Enhanced Oil Recovery

surfactant and polymers helps to check the amount of chemicals required. For example, the use of alkali reduces the consumption of surfactant, which would have otherwise be lost in the reservoir due to their adsorption and retention. Again, the use of polymer checks the usage of alkali. Also the chemicals used are one of those used in our daily routines. For example NaOH, Na2CO3, regular detergents etc. are used in households and are available at very cheap rates. These chemicals can be reused. This makes the ASP flooding method for EOR more economical and feasible to use.

Limitations Even though the ASP method of EOR is very effective in oil recovery, still its use is limited due to various conditions. ◀◀ Method is not profitable in long injection period. ◀◀ Reservoir characteristics, depth of the well, reservoir temperature, salinity, and pH level may affect recovery rate. ◀◀ The higher the viscosity, the higher the sweep efficiency is. But then there is the need for high power motor for the injection of polymer solution. ◀◀ Polymer adsorption and their retention lead to: ◀◀ Laboratory tests often indicate higher adsorption than field performance;

◀◀ Adsorption increases with water salinity increase. ◀◀ This method is not applicable for carbonate reservoirs due to surfactant precipitation by undesired minerals within the reservoir.

Conclusion EOR by chemical flooding is based on two basic mechanisms i.e. the increase of macroscopic efficiency and the increase of microscopic displacement efficiency. Macroscopic efficiency can be improved by polymer injection. The injection of polymer solution increases the viscosity of displacing fluid and reduces the effective permeability to water. The microscopic displacement efficiency can be improved by injection of alkali and surfactant by several mechanism viz.: reduction of IFT, emulsification of oil and water, solubilisation of interfacial films, wettability reversal, etc. The alkaline-surfactant polymer flooding technique has proved from oil field tests more than 20 % OOIP and has been successful in three completed projects in North America as well as several projects in China. Hence, the use of ASP method will curb the energy crisis problems in the future and also for wells.

References [1] Farid Abadli; Simulation Study of Enhanced Oil Recovery by ASP (Alkaline, Surfactant and Polymer) Flooding for Norne Field C-Segment; 567052_FULLTEXT01.pdf;(2012).

[2] A.Y. Zekri and K.K. Jerbi; Economic Evaluation of Enhanced Oil Recovery; zekri_v57n3.pdf; Oil & Gas Science and Technology – Rev. IFP, Vol. 57 (2002).

[3] Vladimir Alvarado, and Eduardo Manrique ; Enhanced Oil Recovery: An Update Review; http://www. mdpi.com/1996-1073/3/9/1529/htm; (2010).

[4] Mr. Saahil Vaswani, Mr. Mohd Ismail Iqbal, Dr. Puspha Sharma; University of Petroleum & Energy Studies, (India); International Journal of Science Technology & Management www.ijstm.com;Volume No.04, Special Issue No.01, (2015).

[5] Abass A. Olajire; Review of ASP EOR (alkaline surfactant polymer enhanced oil recovery) technology in the petroleum industry.

Tarun K

ecovery

Tarun Kumar, Kishan Kumar Gupta, Akshita Agarwal

51

[6] Schmidt, R.L. Thermal Enhanced Oil Recovery – Current Status and Future Needs.January 1990.

[7] Modern Chemical Enhanced Oil Recovery-Theory and Practice (www.knovel.com).

[8] S.M Farouq Ali & S. Thomas, University of Alberta, ‘The Promise and Problems of Enhanced Oil Recovery Methods’ JCPT September 1996, volume 35, No. 7.

[9] Dr. Leonid Surguchev,Vice President,Rogaland Research, Dr. Eduardo Manrique, Questa Engineering Corp., Golden, CO, USA, Prof. Vladimir Alvarado, Catholic Pontifical.

[10] University of Rio de Janeiro, Rio de Janeiro, Brazil. Improved Oil Recovery: Status and Opportunities.

[11] Hourshad Mohammadi, SPE, Mojdeh Delshad and Gary A. Pope. Mechanistic Modelingof Alkaline/ Surfactant/Polymer Floods, the University of Texas at Austin, SPE. [12] R.C. Nelson, J.B. Lawson, D.R. Thigpen and G.L. Stegemeier, Shell Development Co-surfactant Enhanced Alkaline Flooding, SPE 12672.

[13] Sheng, James J. Modern Chemical Enhanced Oil Recovery (Theory and Practice), Elsevier Inc, USA. 2011.

[14] Abe, M., Schechter, D., Schechter, R.S., Wade, W.H., Weerasmriya, U. and Yiv, S. (1986) ‘Microemulsion formation with branched tail polyoxyethylene sulfonate surfactants’, J. Colloid Interface Sci., Vol. 114, No. 2, pp. 342–356.

SPRING/ 2017

How We Do It in Romania?

52

¡¡

Corlean

How We Do It in Romania?

Corlean Oana-Alexandra, Gheorghe Alin-Marian, Balanescu Alexandra Laura

** Oil and Gas University of Ploiesti ÞÞ Romania oana_alexa13@yahoo.com

hydraulic fracturing, for these gases was developped in the US and managed to revolutionize the energy industry, incresing the production with 80% in the past eight years. That has led to an attempt to exploit resources in European countries.

Romania is ranked on the third place in Europe regarding the potential of shale gas exploration.

The first place is occupied by France and Poland, Two of the main issues recently discussed in each with reserves estimated at 5,000 billion cubic  Corlean Gheorghe Balanescu Romania are the deposits of shale Oana-Alexandra, gas, the techmeters, followed byAlin-Marian, Norway. But the big players in  oana_alexa13@yahoo.com nique of hydraulic fracturing, and one of the this field remain US and Canada. It’s estimated that most controversial so Romania could extract 1.44 billion cubic meters of  exploitation Oil and processes, Gas University of Ploiesti called in-situ combustion. shale gas. The only European country which explo Romania ited shale gas by hydraulic fracturing was Poland There are two main questions: whereas in France this technique was forbidden.  University  Country  E-mail

How We Do It in Romania?

Alexandra Laura

Two of the main issues recently discussed in Romania are the deposits of shale

I. Why the Romanian deposits of shale The resources of shale gas have been discovered technique of hydraulic fracturing, and one of the most controversial exploitation proc gas, lying underground, which could proin Romania, in what we, Romanians, call the socalled in-situ combustion. vide us the energy independence, are not uthern part of Moldova, in the Barlad Plateu and exploited and what are the risks brought southern Dobrogea. But the situation is different There are two main questions: here in Romania, where specialists, first of all, need by hydraulic fracturing?

I. Why the Romaniantodeposits shale underground, which could find out if of shale gases gas, can belying exploited, which Shale gas refers to natural gas that trapped within independence, requires a depth drilling.

Romania, for example, usis the energy are not In exploited and what are the risks bro the shale formation. The drilling technique, called shale gas is located at the depth of about 3500-4000

hydraulic fracturing?

Fig. 1

Fig. 1

Shale gas refers to natural gas that is trapped within the shale formation. The

mania?

it takes at least three exploration drillings.

Experts affirmed that the technique of hydraulic fracturing has been us the 60s-70s in conventional oil and gas exploitation. In the deposits of co oil or gas can not get out by natural pressure, it was necessary to introduc quantity of water, which contains a mixture, to mobilize hydrocarbons Corlean Oana-Alexandra, Gheorghe Alin-Marian, Balanescu Alexandra Laura 53 reservoirs. Therefore, the method is not new for Romania.

How does works?

meters. It also crucial to appreciate the size of the geological formations of those fields, whether such exploitation is cost-effective or not, and to perform it it takes at least three exploration drillings.

Experts affirmed that the technique of hydraulic fracturing has been used in Romania since the 60s-70s in conventional oil and gas exploitation. In the deposits of conventional oil, where oil or gas can not get out by natural pressure, it was necessary to introduce under pressure of a quantity of water, which contains a mixture, to mobilize hydrocarbons under the respective reservoirs. Therefore, the method is not new for Romania.

How does the hydraulic fracturing works?

To remove the gas trapped in rock it requires deep drilling, followed by rock pressure injection of a mixture of water, sand and additives. 99.5% of this mixture is water and sand and 0.5% are some chemical additives, substances added to create better circulation of fluids within the well.

These substances would include the addition of bentonite clay powder, a barium sulfate, hematite, or to reduce a viscosity of the fluid in question, a glycol or acrylates.

What are the risks of hydraulic fracturing?

According to specialists the risks of shale gas are: ◀◀ Producing earthquakes up to 2.5 on the Richter scale in areas where wells are drilled and, under certain conditions, water contamination by drilling fluid consisting of water, sand and additives; ◀◀ A risk would be when the drilling columns or cementing the well has not been made perfect, or all the conditions imposed by the technology weren’t considered. That would mean that some of the fluids used in drilling systems interfere with aquifers at various depths ◀◀ There is also a risk that a part of the craks, in certain geological formations, which have or have not come into contact with large amounts of water to come out of their natural balance, and coming out

the hy

Fig. 2

Fig. 2

To remove the gas trapped in rock it requires deep drilling, followed by rock mixture water,balance, sand and of this of their of natural theyadditives. causing a99.5% vibration of mixture is water and san chemical additives, substances added to create better a certain intensity, leading to an earthquake. Such circulation of fluids within

vibrations can cause damage; These substances would include the addition of bentonite clay powder, a bariu ◀◀ reduce Another issue is that thisfluid technology usesa aglycol large or acrylates. to a viscosity of the in question, amount of water.

What are the risks of hydraulic fracturing?

According to specialists the risks ofinvolved shale gas in are: What is the main company

shale gas exploration?

Producing earthquakes up to 2.5 on the Richter scale in areas where under certain conditions, water contamination by drilling fluid consist Chevron, an American company that tried to bring additives; up to the surface thebeshale of Roma-or cementing the well has A risk would whengas thedeposits drilling columns nia. In or 2013 received the permission to all Chevron the conditions imposed by the technology weren’t considered. of the fluids drilling systems interfere with aquifers at vari exploresome the deposits and used madeinan agreement with There is also a risk that afrom part 3.5% of thetocraks, thegovernment to pay royalties 13%. in certain geological form have not come into contact with large amounts of water to come out o and coming out of their natural balance, they causing a vibration of a ce This technique and the risks are involved in the to an earthquake. Such vibrations can cause damage; 

exploration of shale gas lead to protests in villages and in Bucharest, as a result Chevron decided to suspend its activities.

For the moment the Romanian shale gas deposits remain underground…

II. Did you know that Suplacu de Barcau is not only the only place in Romania, where the process of in-situ combustion is applied, but also the largest in the world?

In-situ combustion (ISC) is an enhanced oil recovery method in which the air is injected into the reservoir, burning the heaviest crude oil components generating heat and combustion gases that enhance recovery by reducing oil viscosity and pressurizing the system. In this process, highly exothermic re-

SPRING/ 2017

54 actions occur in the porous medium resulting in significant increases in the temperature.

In-situ combustion has been used in the field since 1920. In the US, more than 230 projects have been implemented. Many of those were technically and economically successful. Failures resulted from: ◀◀ Unfavorable reservoir and fluid characteristics; ◀◀ Poor design; ◀◀ Engineering or operational problems;

going to be produced in the production The reaction heat Corlean How We Do It well. in Romania? the light components of oil in front of the combustion front. distancing from the hot region.

viscosity of crude oil. The fuel of the combustion is mainly Fig. 3composed of asphaltene and heavy fractions of crude oil. These heavy components hinder the production crude oil.

Therefore, the removing Althoughofin-situ combustion method has been widely used fo of these components from crude oil helps the rehas been successfully applied in the light crude oil reservoir covery. In-situ combustion not only removes these decreases the viscosity of crude oil. The fuel of the combu components but also combusts them to make heat asphaltene and heavy fractions of crude oil. These heavy comp and flue gases. The flue gases are miscible in crude crude oil. Therefore, the removing of these components from c oil. Therefore, in-situ combustion includes miscible situ combustion gas injection as well. not only removes these components but also co

flue gases. The flue gases are miscible in crude oil. Therefor miscible gas injectio

Most of the failed projects were small pilot projects implemented in unfavorable reservoirs. Worldwide, combustion accounts for approximately 10% of the oil produced by thermal methods.

Suplacu de

Description of the Method In this method the air is injected to the crude oil reservoir. After ignition, the heat generated by combustion keeps the combustion front moving toward Fig. 4 the producer well. Combustion front burns all the fuel on its way. Usually 5 to 10% of crude oil is used Suplacu de Barcău oil field as fuel and the rest is going to be produced in the production well.ofThe heat vaporizes initial Description thereaction Method The Suplacu de Barcău oil field located in Suplacu water andmethod also thethe lightair components in front In this is injectedoftooilthe crude oil reservoir.

After ignition, the isheat generated de toward Barcău, Bihor County. Itwell. was discovered in 1956 ofbythecombustion combustionkeeps front. The is condensed the steam combustion front moving the producer Combustion byused Petrom. while the hot region. frontdistancing burns all from the fuel on its way. Usually 5 to 10%and of developed crude oil is as fuel and the rest is The reservoir is located in the Northwestern part of Romania, 70 km from the town of Oradea. It is a Panonian formation, and it was formed by the moulding of the underlying crystalline basement The Suplacu de Barcau project uses a dry ISC process conducted at low pressure (less than 1.4 MPa or 200 psi) in a very shallow reservoir (less than 180 m or 600 ft) using a small well spacing (50 to 100 m distance between wells).

Fig. 3

The total proven reserves of the Suplacu de Barcăuheat oil field are around million barrels going to be produced in the production well. The reaction vaporizes initial310 water and also (43.7×106 and production is centered the light components of oil in front of the combustion front.tonnes), The steam is condensed while on Although in-situ combustion method has been 8,500 barrels per day (1,350 m3/d). distancing from the hot region. widely used for heavy crude oil reservoirs, it has been successfully applied in the light crude oil reSuplacu de Barcau is the world’s largest combuFig. 3 servoirs. The increase in temperature decreases the stion project; it started in 1964 and is operated in Although in-situ combustion method has been widely used for heavy crude oil reservoirs, it has been successfully applied in the light crude oil reservoirs. The increase in temperature decreases the viscosity of crude oil. The fuel of the combustion is mainly composed of asphaltene and heavy fractions of crude oil. These heavy components hinder the production of crude oil. Therefore, the removing of these components from crude oil helps the recovery. Insitu combustion not only removes these components but also combusts them to make heat and flue gases. The flue gases are miscible in crude oil. Therefore, in-situ combustion includes

mania?

The Suplacu de Barcău oil field is located in Suplacu de Barcău, Bihor County. It was discovered in 1956 and developed by Petrom.

Corlean Oana-Alexandra, Gheorghe Alin-Marian, Balanescu Alexandra Laura 55 The reservoir is located in the Northwestern part of Romania, 70 km from the town of Oradea.

It is a Panonian formation, and it was formed by the moulding of the underlying crystalline All in all, in-situ combustion is a method of crude a line-drive mode from the top downward. Videle basement. oil recovery in which the air is injected to the cruand Balaria are other in-situ combustion projects.

It represents an East-West oriented anticline upfold, axially tofaulted the fractions major fault de oil reservoir burn thebyheavy of the of oil and make heat to ease the production.

With 5000 Suplacul de Barcau is RomaSuplacu dewells, Barcau, limiting the field to the South crude and East.

Combustion of crude oil is a very complex process nia’s largest oil field. Although the financial part The Suplacuthe deliving Barcau project uses a dry ISC process conducted at low pressure (less than and the complexity of transport makes it even more has improved standard, there are voices 1.4 MPa or 200 psi) in a very shallow reservoir (less than 180 m or 600 ft) using a small well difficult to model and engineer. complaining about the excessive pollution of water spacing and land.(50 to 100 m distance between wells).

Fig. 5

Fig. 5

References

The total proven reserves of the Suplacu de Barcău oil field are around 310 million barrels [1] https://en.wikipedia.org/wiki/Shale_gas_in_Romania.

6 tonnes), and production is centered on 8,500 barrels per day (1,350 m3/d).

(43.7×10 Suplacu de Barcau is the world’s largest combustion project; it started in 1964 and is operated [2] https://en.wikipedia.org/wiki/2012%E2%80%9314_Romanian_protests_against_shale_gas. in a line-drive mode from the top downward. Videle and Balaria are other in-situ combustion projects.

[3] http://www.shale-gas-information-platform.org/what-are-the-risks.html.

With 5000 wells, Suplacul de Barcau is Romania’s largest oil field. Although the financial [4] http://www.zf.ro/business-international/gazele-de-sist-in-polonia-o-bula-sparta-15368940. part has improved the living standard, there are voices complaining about the excessive pollution of water and land.

[5] http://www.mediafax.ro/economic/chevron-renunta-la-explorarea-gazelor-de-sist-in-romania-proiectul-nu-poate-concura-cu-alte-oportunitati-globale-13866202.

All all, in-situ combustion is a method of crude oil recovery in which the air is injected to [6] in http://petrowiki.org/In-situ_combustion. the crude oil reservoir to burn the heavy fractions of the crude oil and make heat to ease the [7] http://large.stanford.edu/courses/2010/ph240/bazargan1.

[8] S.M Farouq Ali & S. Thomas, University of Alberta, ‘The Promise and Problems of Enhanced Oil Recovery Methods’ JCPT September 1996, volume 35, No. 7.

[9] http://www.ebihoreanul.ro/mobile/index.php?&categ_id=6&categ_name=qmlob3jlyw5..&news_ id=110112&action=display_news.

SPRING/ 2017

‘Oil and Gas Horizons’ 2016

56

¡¡ ‘Oil and Gas Horizons’ 2016 VIII International Youth Scientific and Practical Congress “Oil and Gas Horizons” took place on the 23–25 of November, 2016 at the Gubkin University. The Congress was organized by the Society of Petroleum Engineers (SPE) Student Chapter of the university. More than 150 graduate and post graduate students from 37 universities and 18 countries participated in the Congress.

The Congress is increasing in scale each year: the geography of participants is widening, the level of presented scientific papers is growing, the support of sponsors and the university is intensifying, and the brand is becoming more famous. This year the Gubkin University was visited by graduate and post graduate students from Austria, Australia, Azerbaijan, Brazil, China, Croatia, Egypt, Germany, India, Iran, Kazakhstan, Nigeria, Poland, Romania, South African Republic, Ukraine, the USA, and, of course, Russia. The event was supported by the leading international and national oil and gas companies, SPE Moscow Section, and SPE Regional Office. Halliburton and Salym Petroleum became the Golden Sponsors of the event, Schlumberger – the Silver, Rock Flow Dynamics – the Exclusive Sponsor, LUKOIL and Gubkin Print – the Partners of the Congress. The following journals became media partners of the event: Nedra, ROGTEC, Oil &

Gas Eurasia, Oil & Gas Offshore, YoungPetro, and also several student organizations: Gubkin television GUtv, the Poisk newspaper, and the Kerosin magazine. During these three days 80 volunteers, students from the Gubkin University, worked on various objectives of the Congress.

The Opening Ceremony was attended by the Vice-Rector for International Affairs of the Gubkin University, Alexander Maximenko, 2018 SPE President, Darcy Spady, the Director General for business development at Halliburton, Dmitry Chasovskih, the HR Vice-President at Schlumberger, Sergey Pershin, the manager for business development at Rock Flow Dynamics, Ivan Rogachev, the SPE Russia and Caspian Regional Director, Anton Ablaev, and the executive assistant of rector and student projects coordinator of SPE Moscow Section, Vlada Streletskaya.

Corlean

s’ 2016

Corlean Oana-Alexandra, Gheorghe Alin-Marian, Balanescu Alexandra Laura

After the words of welcome the Plenary Session took place. Each year the subject of the Plenary Session is chosen, based on the most actual problems in the petroleum industry. This year the subject was “The Arctic – words to actions”, and it was also the main subject of the entire Congress. The presenters revealed the current condition of Arctic zones of Canada, Russia, and other countries, which have the access to the Arctic Shelf. The list of the presenters is following: 2018 SPE President Darcy Spady, a representative of the Schlumberger company, Dmitry Zavornov, Anton Sungurov, the Head of the Rystad Energy Russia and CIS Office, Anatoly Zolotukhin, a professor at the Gubkin Russian State University of Oil and Gas (National Research University).

The main goal of the students, who arrived from all over the world, was to present their scientific papers and exchange knowledge and experience with each other at the Student Paper Contest, which included the following directions: ◀◀ ◀◀ ◀◀ ◀◀ ◀◀ ◀◀ ◀◀ ◀◀ ◀◀ ◀◀

Geosciences; Drilling and Completion; Oil & Gas Field Development; Transportation and Storage; Oil & Gas Chemistry; Health, Safety and Environment; Petroleum Economics and Management; Alternative Energy Sources and Sustainability; Offshore and Arctic Petroleum Engineering; PhD Paper Contest.

And the following special sessions: ◀◀ Young Professionals Paper Contest; ◀◀ Poster Session.

The participants shared their technical inventions and ideas and the experts evaluated their work, choosing 3 best papers in each session. The expert teams included teachers from the Gubkin University, a lecturer from the La Sapienza University, Rome, Italy, and also representatives of several companies: Halliburton, Schlumberger, Shell, Total, Schlumberger, Exxon Neftegas Limited, Salym Petroleum Development, PCC Exol SA, Gazprom, Katod, LUKOIL-Engineering, Gazprom VNIIGAZ, Zarubezhnft and Gazprom Neft.

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Another memorable event of the Congress was the Soft Skills Training by 2018 SPE President, Darcy Spady, where he shared his career pathway with the future professionals and also met the Vice Rector for International Affairs of the Gubkin University, Alexander Maximenko. During this meeting Mr. Spady pointed out high level of equipment and laboratories at the university.

The second day of the Congress began with the project of SPE International ‘Career Pathways Fair’, which had been organized at the Gubkin University for the first time. The goal of this project is to enable the students to find out more about all aspects of the Petroleum Industry. Specialists, representing different companies, told the participants about the specific nature of their work, innovations in their field, and answered many questions. The following companies were represented at the fair: Halliburton, Schlumberger, Salym Petroleum Development, Repsol, General Electric, LUKOIL-Engineering, Katod, Gazprom, Gazprom avtomatizatsiya, and Gazprombank. During the event Schlumberger organized a contest, and gave out prizes to the winners. Apart from that, a stand of the Gubkin University was presented at the fair, and the representatives from other universities could find out about the educational process, building academic career, potential education opportunities and the university infrastructure.

The next event was the intellectual game PetroOlympic Games, traditionally held during the Congress, which was sponsored by Halliburton. In order to participate in the game, interested students had to undergo an online qualification round, and also film a motivational video. As a result, five teams of people from different professional areas and countries, were formed. After 3 rounds the experts from Halliburton chose the best team: “InterOil”.

“For me the participation in this event is a priceless experience and a great achievement. It was a great opportunity for all participants to demonstrate their knowledge about the petroleum industry, and I am very glad I met such amazing people from different cities and countries” Aygul Murtazina, member of winning team

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In the second half of the day the participants of the Congress took part in Round Table discussions – International and Regional. The International Round Table was dedicated to the following subject ‘Perspectives of establishment, support and development of international relations between SPE student chapters worldwide’. The event was attended by representatives from 9 chapters from all over the world: from the USA to Australia. A presentation about the crucial importance of international friendship and partnership for the young generation – the people who will determine the direction of development of the industry and the entire world, was introduced to all participants.

Apart from that, representatives of each SPE student chapter presented their chapter and suggested the most efficient, in their opinion, way for the development of international relations within the global SPE community. Apart from that, each chapter presented a project which has a certain potential to be realized on an international level by joint forces of all participants of the event. As a result, the Resolution of the International Round Table, reflecting key results of the discussion, was written down. 2018th SPE President Darcy Spady, who was a special guest at the event, made priceless contribution to the dialogue with his advice and comments to each of the presenters.

‘Oil and Gas Horizons’ 2016

At the same time as the International Round Table, the SPE Russia and Caspian Regional Round Table was held. Anton Ablaev, the SPE Russia and Caspian Regional Director, together with representatives of the SPE Regional Office and SPE Moscow Section had a meeting with the officers of SPE student chapters in the region. Fresh news of the Regional Office were announced, and issues of development of regional SPE student chapters were discussed, and also the possibility of organization of conferences by these chapters.

The uniqueness of Third Youth BRICS Summit in the Oil and Gas Industry, which was also held on the 24th of November, was the new format, introduced this year – the Summit was conducted in the form of workshop, entitled ‘Ecology and Energy Saving’. The Summit was opened with a speech from the Vice Rector for Educational and Methodical Management, Andrei Dushin. The first part of the Summit was the meeting of members of Youth International BRICS Countries Association of Petroleum Universities, during which the participants from different countries found out more about the actions of the Gubkin University, regarding the development of BRICS Youth direction, and discussed the location of the next Summit. The second part of the Summit was work on team pro-

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Corlean Oana-Alexandra, Gheorghe Alin-Marian, Balanescu Alexandra Laura

jects. The participants, who were divided in teams in advance, presented their projects, dealing with one of the ecological problems in the petroleum industry. While working on their projects, the participants had the opportunity to consult economics and ecology specialists, and also technical experts.

In the end the participants presented their works to expert team, which included representatives of Gazprom and the Gubkin University. The team, who ended up as a winner presented the project, entitled ‘Rationalization of energy resources use in the production process’.

The second day of the Congress ended with the Closing Ceremony and Gala Dinner at Culture Palace ‘Gubkinets’. The Official sponsor of this event was Rock Flow Dynamics Company. 2018 SPE International President, representatives of companies, the university, Moscow Professional Section and also SPE Regional Office awarded the winners of technical sessions, PetroOlympic Games, the authors of the best BRICS Summit project, and also winners of “The Golden Legacy” stipend, which was granted by the World Petroleum Council. Video greeting by the Deputy Minister of Education of the Russian Federation Veniamin Kaganov, and the Minister of Natural Recourses and Ecology of

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the Russian Federation Sergey Donskoy was presented at the Ceremony. The Gala Dinner and the Awarding Ceremony also included artistic performances, which were prepared by the Association of Creative Students of the Gubkin University, and also guests and volunteers of the Congress.

Educational event Energy4me was also included in the program of the Congress. This program is intended for high school students. Representatives of three schools were invited to the Gubkin University: School № 1368, School № 56 and School № 2097. The pupils learned about the basics of the petroleum industry. The following aspects were unrevealed: classification and basic principles of increased oil recovery methods, and also offshore and onshore oil spill elimination. Apart from the theoretical part the following experiments were demonstrated: ‘Peak of oil production’, ‘Oil filtration examination’. The professors from the Faculty of Chemical and Environmental Engineering held a master-class on oil fractional distillation, which was very interesting for all attendees. After this the students visited the Drilling Department, where the well operation training simulator was shown to them.

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The participants of the STC 2016 gathered at the German Oil Museum in Wietze – the birthplace of the German petroleum industry. Photo courtesy by Daniel Bücken.

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STC 2016, Wietze, Germany

On the 3rd and 4th of November 2016 the Student Technical Conference – the STC 2016 – took place in Wietze. The outstanding program of this two-day event was organized by the German Section of the Society of Petroleum Engineers (GSSPE) and its associated SPE student chapters. Again, the unique and historic setting of the German Oil Museum in Wietze served as the traditional venue for this event.

In the last several years the conference has established itself as a prime event to learn about the latest research projects in academia and covers disciplines such as petroleum-related geosciences and geothermal energy, reservoir engineering, drilling and production. The event was opened with welcoming words of Dr. Oksana Zhebel, the first female chairperson of the German Section SPE. During 13 technical presentations and an extended poster session numerous talented students presented their fresh ideas and innovative concepts in front of a broad professional audience of about 100 people. The students from the associated SPE

student chapters in Aachen, Bochum, Freiberg, and Clausthal as well as student presenters from other renowned universities in Germany, Austria, India, Portugal, Russia and Ukraine started professional as well as informal discussions with each other and with the representatives of the petroleum industry – their potential employers. Many opportunities for networking were given during coffee breaks in the exhibition area and during the conference dinner.

Selected volunteers and student chapters were awarded by Matthias Meister (SPE regional director for South, Central and East Europe) during the

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Corlean Oana-Alexandra, Gheorghe Alin-Marian, Balanescu Alexandra Laura

The final day of the Congress was dedicated to visiting companies. 45 people, divided in several groups visited different companies: Halliburton, Salym Petroleum Development, Deloitte, LUKOIL and MZTA Engineering, and also the most advanced departments of the Gubkin University. The visits included presentations about the companies’ activities, meetings with the managers of those companies, demonstrations of the latest achievements, and Q/A sessions. At Halliburton the Vice President of the Company, Konstantin Shilin spoke about the company’s mission and his career. During the excursion at Salym Petroleum Development, the visitors learned about the main projects of the company and received gifts. At LUKOIL apart from the presentation of the history of the petroleum industry in Russia, the guests could see the exhibits in the LUKOIL museum. At MZTA Engineering latest innovations in the sphere of building automated gasoline stations were shown. The Deloitte company revealed the current situation in the global petroleum industry and its perspectives, and also presented the company’s activity. At the Gubkin University the participants visited the one-of-a-kind Field Development Distance Control Centre, and the offshore oil platform operation simulator, made by NOV, and also enjoyed an excursion to the university museum.

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Another important goal of the ‘Oil and Gas Horizons’ Congress was the introduction of the main sights and traditions of the Russian capital to the visitors. In the afternoon on the 25th of November a cultural program was organized. Three routes were available for anyone who wanted to join: these routes included a visit to the Red Square, Moscow city business center, or the Patriarshy Pond. The guests could see the busy center of Moscow, or enjoy a walk in the quiet alleys and corners of the capital.

VIII International Youth Scientific and Practical Congress ‘Oil and Gas Horizons’ became a unique platform which brought together representatives of the best universities and companies in the world.

Participants and guests spent three very fruitful days, discussing current issues in the petroleum industry, exchanging ideas and experience, and networking.

“I always offer your Congress as an example for other SPE Student Chapters. It definitely is the best student petroleum conference, organized by SPE student members and university activists in Russia, in the region and perhaps in the whole world” Anton Ablaev, the SPE Russia and Caspian Regional Director, Kerosin magazine

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award ceremony to express their contributions to the community: Regional Service Awards were handed over to Hernan Bujs and Rainer Wilhelm, Oksana Zhebel received the Regional Young Member Outstanding Service Award and the members of the Montan University Leoben and TU Bergakademie Freiberg celebrated winning the Gold Standard Student Chapter Awards.

Based on exciting questions – which were prepared by the curious audience – Caroline Kannwischer (engie), Samir Alakbarov (Wintershall), Max Arndt (BakerHughes) and Sebastian Thronberens (Weatherford) shared their first individual experiences as young professionals in the petroleum industry during the YP panel “Transitioning into the workforce – pitfalls, strategies, experiences”. It became clear that networking skills, integrity and flexibility are some of the most important prerequisites for a successful early career.

In his powerful speech Matthias explained the mar-

STC 2016, Wietze, Germany

ket’s actual situation and presented the advantages of membership in the Society of Petroleum Engineers. Particularly, he emphasized the actuality of the SPE vision which more than ever demonstrates the necessity for a strong community behind an affordable energy supply for the global population in a safe and environmentally responsible manner.

The key note lecture “The future of the German E&P industry and the role of the business organization” by Dr. Christoph Löwer, (managing director of the Bundesverband Erdgas, Erdöl und Geoenergie e.V., BVEG) triggered a vital discussion about political and economic limitations inside and outside Germany, the large advantages, responsibilities and opportunities of the domestic petroleum industry as well as possible ways to use social media as a method for communication between the industry and the public. He explicitly warned about a gradual decline in domestic gas production if the actual business remains before he finally pointed out the importance of interdisciplinary cooperation

The STC traditionally serves as a platform for students to present their research projects, to learn about trends in the petroleum industry and it offers many networking opportunities. Photo courtesy

by Daniel Bücken.

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The German Oil Museum in Wietze populated by a crowd of students and professionals, carefully listening to the interesting lectures of the student presenters from petroleum-related sciences. Photo courtesy by Daniel Bücken.

of all industry sectors (renewables and petroleum) in the scope of the growing demand for safe and affordable energy, the persistent public “technophobia” and the social changes related to the German energy transition.

these troubled times: the professional organizers and the student chapters stacked their heads together and reduced the costs, while many generous sponsors were acquired and made the final realization possible despite the actual market situation.

The STC has evolved to a conference with spearheading presentations and posters, setting a mark in science. However, it is also a place to gather with a personal note – to meet old friends and make new ones.

On behalf of all the students who participated in the STC 2016 we want to thank all sponsors, helpers and participants for their contribution to this successful event. Further, we are extraordinary grateful for the dedicative engagement of the lead organizers Ulrike Peikert and Ingo Forstner.

After all, the Student Technical Conference 2016 was a bright ray of hope for our community during

It was a great event and we are looking forward to the next year’s STC.

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How Does It Work?  How It Works?

Introduction

Wojciech Kurowski

From the beginning of the oil and gas industry, engineers have striven to reach optimization of working time systematize the gasselection tools.

Fora universal this reason thecode International Fromand the beginning of the oil and industry, en-of drilling arches and compiled code. This have striven to reach optimization worisresearches still in use andand consists of three digits and one code. This Associationgineers of Drilling Contractors (IADC)ofconducted compiled a universal king time and systematize the selection of drilling letter.

Its main task is to characterize the type of the type of code is still in use and consists of three digits and one letter. Its main task is to characterize tools. For this reason the International Association roller bits and its properties with regard to the type roller bits and its properties with regard to the type of rock formations. of Drilling Contractors (IADC) conducted reseof rock formations.

D1

D2

D3

D4

The first digit is assigned number between standard 1 andopen 8 specifying theType type drilling tools The first(D digit is assigned aanumber between bearing roller bits.

2 isof for air1) (D1) andtype 8 specifying the type drilling tools (espe- corresponding -cooled bearings type 3 is standard open of the rock (especially 1the of teeth) andofsimultaneously the and increase infor the hardness bearing roller bits with exterior reinforcement. formations.cially the type of teeth) and simultaneously corre-

sponding the increase in the hardness of the rock Numbers: 1, 2 and 3 characterize a Numbers: 4 and 5 characterize sealed roller bearinNumbers: 1,formations.

2 and 3 characterize a steel tooth bits (from soft rock formations to hard formations). steel tooth bits (from soft rock formations to hard gs. Type 4 is for standard sealed roller bearing bits formations).Numbers: 4, 5, 6, 7 and 8 characterize and type 5 is for standard sealed roller bearing bits Numbers: 4, 5, 6, 7 and 8 characterize a tungsten carbide insert bits (from soft rock formations to hard a tungsten carbide insert bits (from soft rock forwith external protection. formations).mations to hard formations).

Numbers: 6 and 7 characterize journal sealed beThe secondThedigit (Ddigit ascribed a anumber betweenarings.

1 and the type drilling tools, 2) is second (D2) is ascribed number beType46 isqualifying for standard journal sealed of bearing tween 4 qualifying the type drilling tools, bits and type 7 is for standard journal sealed bearing depending on the1 and hardness of the rockof formations. depending on the hardness of the rock formations. bits with exterior strengthening.

1, 243 and 4 characterizethe the hardness of of rock formations. Type 1 corresponds to drill bits Numbers: 1,Numbers: 2 3 and characterize hardness rockrock formations.

Type 1 corresponds bits for The fourth digit (D4) is ascribed a letter between for the softest formations and typeto4drill corresponds to the hardest ones. the softest rock formations and type 4 corresponds A and Z indicating additional properties of drilling to the hardest tools.7 indicating the structural features of drilling The third digit (D ) isones. assigned a number between 1 and 3

tools: bearing types and availability of reinforcement ofA –external parts of bits.

The third digit (D3) is assigned a number between Air application; B – Special bearing; C – Cen1 and 7 indicating the structural features of drilling

tral jetted; D – Deviation control; E – Extended

Numbers: 1,tools: 2 and 3 characterize open ofroller bearings.jets; Type is for standard open bearing bearing types and availability reinforceG–1 Extra gauge/Body protection; H – Ho- roller bits.

Type 2 is for air-cooled bearings and type 3 is for standard open bearing roller bits with exterior ment of external parts of bits. Numbers: 1, 2 and rizontal/Steering application; J – Jet deflection; 3 characterize open roller bearings. Type 1 is for L – Lug pads; M – Motor application; S – Stanreinforcement.

Numbers: 4 and 5 characterize sealed roller bearings. Type 4 is for standard sealed roller bearing bits and type 5 is for standard sealed roller bearing bits with external protection.

Numbers: 6 and 7 characterize journal sealed bearings. Type 6 is for standard journal sealed bearing bits and type 7 is for standard journal sealed bearing bits with exterior strengthening.

The fourth digit (D4) is ascribed a letter between A and Z indicating additional properties of drilling tools.

A – Air application; B – Special bearing; C – Central jetted; D – Deviation control; E – Extended jets;

Wojciec

ermany

How Does It Work?

InWojciech order toKurowski explain how to use IADC code it is necessary to give an example.

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“After drilling 120 meters in poorly compacted clays, the drilling tool equipped with steel tooth encountered hard abrasive rocks such as sandstones with quartz binder and hard quartz shale. These new formations require application of different type of drilling bits. dard steel tooth; T – Two cone; W – Enhanced cutting structure; X – Chisel inserts; Z – Other Additional information: Compressive strength is shape inserts.

things. First of all, we should pay attention to the type of rock formation and compressive strength. about 45 MPa”.

Secondly, we should consider possible risks which may appear inside the borehole. Eventually, we can Based on the above information, we need to interpret provided data and extract the most important How Does It Work? select properties of drilling tool which may be usethings. First of all, we should pay attention to the type formation and compressive strength. ful inof therock later process.

Secondly, we should consider risksit iswhich may appear inside the borehole. Eventually, we can In order to explain how to possible use IADC code necessary to an example.

Solution Does It Work? select properties ofgive drilling tool which may beHow useful in the later process.

In order to explain how to use IADC code it is necessary to give an example.

The first digit (D1): Due to encountering hard abraSolution “After drilling 120 meters in poorly compacted “After drilling 120 meters in poorly compacted clays, the drilling tool equipped with steel tooth encountered hard abrasive such are as sandstones with quartz hard quartz shale. These clays, the drilling tool equipped with steel tooth sive rocksrocks which characterized bybinder highand hardness new formations require application of different type of drilling bits. encountered hard abrasive rocks such as sandstones we can pick only the number 3, 6, 7 and 8.

The first digit (D1): Due to encountering Additional hard information: abrasive rocks which are characterized by high Compressive strength is about 45 MPa”. with quartz binder and hard quartz shale. These hardness we can pick only the number 3, 6, 7 Based andon8.the above information, we need to interpret provided data and extract the most important new formations require application of different type The second digit (D2): The high hardness allows things. First of all, we should pay attention to the type of rock formation and compressive strength. of drilling bits. us toconsider selectpossible only risks the which number 3 andinside 4. the borehole. Eventually, we can Secondly, we should may appear

The second digit (D2): The high hardness allows us toofselect only thebenumber 3 process. and 4. select properties drilling tool which may useful in the later Additional information: Compressive strengthSolution is

The third digit (D3): The presence of sandstones

The third about digit45(D with (Dquartz binder and abrasive hard quartz shale oblige us to 3): The presence of sandstones The first digitwith ): quartz Due to encountering rocksshale whichoblige are characterized by high MPa”. binder andhardhard quartz us hardness we canrange pick only from the number43,to 6, 7 7. and 8. use sealed or journal sealed bearings. Numbers in the to use sealed or journal sealed bearings. Numbers 1

The second digit (D2): The high hardness allows us to select only the number 3 and 4.

Based on the above information, we need to interin the range from 4 to 7.

The third digit (D ): The presence of sandstonesA withand quartzZ. binder and hard quartz shale oblige us to The fourthpret digit (D4): Depending onmost ourimportant requirements.

Letter between provided data and extract the 3

use sealed or journal sealed bearings. Numbers in the range from 4 to 7.

The fourth digit (D4): Depending on our requirements. Letter between A and Z.

D1=3

D2=3

D3=5D =3 DD 4=5=GD =G

D1=3

2

3

4

IADC: 335G indicating steel tooth, sealed roller bearing bits with external reinforcement for hard semi-abrasive and abrasive formations. Additionally, extra body protection.

Conclusion

Theindicating fourth digit (D4): on our requireSources IADC: 335G steelDepending tooth, sealed roller bearing bits external reinforcement hard To sum up, IADC code is an with extraordinary tool which helps engineers to describe for what kind of roller bits they are looking for from the supplier. ments.

Letter between A and Z. semi-abrasive and abrasive formations. Additionally, extra body protection.

[1] www.bitbrokers.com Sources IADC: 335G indicating steel tooth, sealed roller [2] www.bestdrillingbits.com [1] www.bitbrokers.com Conclusion bearing bits with external reinforcement for hard [3] www.burintekh.com [2] www.bestdrillingbits.com semi-abrasive and abrasive formations. Additional[3] www.burintekh.com To sum up, IADC code is an extraordinary tool which helps engineers to describe what ly, extra body protection.

kind of roller

bits they are looking for from the supplier.

Sources

Conclusion To sum up, IADC code is an extraordinary tool

[1] www.bitbrokers.com which helps engineers to describe what kind of roller bits they are looking for from the supplier.

[2] www.bestdrillingbits.com [3] www.burintekh.com

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