Petroleum Today Magazine 38

Volume 38 October 2019

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MEDITERRANEAN LNG MARKET EVOLUTION

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COOPERATION PARTNERS

Alex Office: Address: P.O.Box 114 Elsaray 242 Abdel Salam Aref st., Loran, APT. 103, Alexandria, 21411, Egypt Phone: +20 (3) 5833301 - 5833294 Fax: +20 (3) 5823514 Email: catec@catecegypt.com

W W W. C AT E C E G Y P T. C O M

Cairo Office: Address: 2B Nozha st., Heliopolis, APT. 7, Cairo, 11341, Egypt Phone: +20 (2) 24145127 / +20 (2) 24145128 Fax: +20 (2) 24145129 Email: catec.cairo@catecegypt.com

Alex Office: Address: P.O.Box 114 Elsaray 242 Abdel Salam Aref st., Loran, APT. 103, Alexandria, 21411, Egypt Phone: +20 (3) 5833301 - 5833294 Fax: +20 (3) 5823514 Email: catec@catecegypt.com

W W W. C AT E C E G Y P T. C O M

Cairo Office: Address: 2B Nozha st., Heliopolis, APT. 7, Cairo, 11341, Egypt Phone: +20 (2) 24145127 / +20 (2) 24145128 Fax: +20 (2) 24145129 Email: catec.cairo@catecegypt.com

M I C O P E R I

Above, the main vessel DLV SEMINOLE assisted by cargo barge and tugs is in operation at El-Hamra Field to install a 36�x8.5 km subsea pipeline at El-Alamein, Egypt, in the Med Sea. The pipeline shall import and export crude oil between El-Hamra facility and tankers through a new offshore SBM system, including a new CALM buoy single point mooring, anchor legs, mooring hawser, floating hoses assembly and manifold (PLEM), for the tie-in to the onshore existing plant.

Main Contractor: Petroleum Marine Services (PMS), Egypt Client: Western Desert Operating Petroleum Company (WEPCO), Egypt

1 Ahmed Kamel Street Off Lasilky (CIB Building) New Maadi-Cairo, Egypt T : +202 25166064 F : +202 25166046 M : +201000360107 E : sgiddio@eos-eg.com w : www.micoperi.com

Petroleum Today Contents

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60 74 96

Back to the Pearl of the Mediterranean News Talent & Technology A Business Case for Environmental Solutions Well control Safety and Regulations on Deep Water and Onshore wells Electrical Submsersible Pump Powered Injection ESPPI Systems Enable the Development of West of the Nile Egypt Assets Integrating Big Data: Simulation, Predictive Analytics, Real Time Monitoring, and Data Warehousing in a Single Cloud Application Environmental Mainstreaming for SelfRegulation EMSR Industry At A Glance

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MEDITERRANEAN LNG MARKET EVOLUTION

‫ اتفاقيات تعاون مع ش���ركات البترول‬4 ‫البت���رول توق���ع‬ ‫العالمية العاملة فى مصر‬ ‫ الف برميل‬700 ‫مص���ر تخطط لرفع انتاج الزيت الخام الى‬ ‫يوميًا‬ ‫ شل ما زالت تملك الشهية لالستثمار‬:‫الرئيس التنفيذي‬ ‫في الشرق األوسط‬ ‫حوار بترولي���م توادى مع المحاس���ب محمد مصطفى‬ ‫رئيس شركة إبسكو‬

2 3 4 8

Petroleum Today Chairman Mohamed Bendary

Back to the Pearl of the Mediterranean

T

he Government of Egypt continues to demonstrate a very strong commitment to embrace new and emerging analytical fields providing the Oil and Gas industry with groundbreaking methods evolving in this way, the needs of future generations.

The recent gas discoveries have contributed to repositioning Egypt in the oil and gas industry both on the regional and international levels. And while such big discoveries represent an economic blessing, they still carry with them a lot of hard work and necessary collaborative efforts for the best monetization of the region’s natural resources.

All these factors along with Egypt’s strategic location and well-established infrastructure have greatly contributed to making Egypt a regional energy hub, which has in turn made the establishment of the East Mediterranean Gas Forum (EMGF) inevitable.

I take great pride in welcoming all participants to the legendary city of Alexandria to attend the 10th Edition of the Mediterranean Offshore Conference (MOC). This beautiful city known as “The Pearl of the Mediterranean” simply resonates with the richness of its history and culture, maintaining and atmospheric juxtaposition between old and new.

The Conference is held this year under the theme “EGYPT: Connecting the two shores of the Mediterranean”, promoting regional coordination of efforts and cooperation.

You will enjoy the readership of MOC show daily news through the coverage of petroleum today editors updating your insight with minute on minute events in the conference, exhibition and gas club in cooperation with Shell E&P. We would like invite all visitors, exhibitors, company leaders and professionals who have the vision, the knowledge and experience to visit our booth at the MOC venue getting the unrivalled publications from Petroleum Today.

In the end, greetings to you, Egypt has pride and dignity

Petroleum Today

Vice-Chairman Ali Ibrahim Executive Editor-in-Chief Magdy Bendary Scientific Secretary Ali Afifi Marketing Mahmoud Mabrouk Medhat Negm Magdy Ahmed Athar Yousry Senior Editor Osama Radwan Editing Staff Mohamed Ahmed Magdy Rashid Financial Management Wael Khalid Art Director Walid Fathy Office Manager Marwa Negm Photography Mohamed Fathy Scientific Staff Dr. Attia M. Attia Dr. Adel Salem Dr. Ahmed Z. Nouh Dr. Ismail Aiad Dr. Gamal Gouda Eng. Mahmoud A. Gobran Eng. Mohamed nada Eng. Taher Abd El Rahim Eng. Mohamed Bydoun Eng.Samir Abady Dr. Lubna Abbas Saleh Special thanks to all the Society of Petroleum Engineers (SPE) Mr. Hany Hafez All opinions expressed through the magazine is pertaining to their authors & don,t express the magazine,s point of view Publisher & Distribution The Egyptian Company For Marketing 29th Abd El - Aziz Gawesh st. Lebaonon Sq., Mohandeseen Giza - Egypt Tel. : +202 33050884 Mob.: 01006596350 Mob.: 01000533201 E-mail: petroleum.mag@gmail.com E-mail: mohamed@ petroleum-today.com www.petroleum-today.com Copyright Reserved Design and Print by:

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egypt news Talks with German Ambassador on the Partnership Developments between Both Countries

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ng. Tarek El Molla, Minister of Petroleum and Mineral Resources, received Dr. Cyril van Nun, German Ambassador to Cairo, in his first meeting after taking over his responsibilities in Egypt. They discussed cooperation domains concerning oil and gas industry, in light of the strong bonds and extended economic partnership relations between both countries, as well as the successful projects for oil and gas development and production.

During the meeting, they reviewed the current status of the German companies operating in Egypt; and their activities in the exploration and production domains, in addition to pointing out the project of transforming Egypt into a regional hub for oil and gas trade.

Moreover, El Molla highlighted the EU’s support to Egypt in implementing its project as a regional hub for oil and gas trade, which was clearly reflected by the European Commissioner for Energy and Climate’s visit to Egypt last year, as it witnessed signing a number of MoUs in this regard. He also affirmed the EU,s financial and technical support for the project.

The meeting, as well, discussed the role of the East Mediterranean Gas Forum and its objectives, represented in fostering cooperation, partnership and coordination among member countries for achieving best economic exploitation of the gas resources in the region, as well as achieving integration between these countries in exploiting the available infrastructure and natural gas resources.

Egyptian LNG to return to full operation

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gyptian LNG (ELNG) facility will return to 100pc of nameplate capacity, the firm’s senior optimization manager Tamer Abdelsalam told the Gastech conference in Houston. It is currently operating at 90pc capacity.

Full output is a far cry from the dark days of mid-2013 to mid-2019, when the volume of feed gas reaching the plant

hovered at 1315-pc of design capacity. During that period, ELNG produced just 31mn m³ of LNG and exported 21 cargoes, bring in only $354mn in revenues, says Abdelsalam.

The return of ELNG, located at Idku, to full capacity may not, though, be followed swiftly by a full restart of Egypt’s other export terminal at Damietta. “That is for the government,” says Adelsalam. “They are taking the lead in negotiations around Damietta.”

The vast majority of feed gas into ELNG is coming from the offshore Simian and Sapphire fields, with just a very small proportion supplied by the national grid, say Abdelsalam.

That obviously raises questions around Egypt’s existing LNG infrastructure’s capacity to export gas not just from Egypt but also from East Med neighbors Cyprus and Israel.

12 Petroleum Today - October 2019

Eni Starts Production of Baltim South West Field

E

ni announces the successful commissioning and start-up of production of the offshore Baltim South West gas field in Egypt.

Discovered by Eni in June 2016, the field goes on-stream in a record time, just 19 months after the final investment decision (FID) was approved in January 2018. This result further confirms the success of the strategy adopted by Eni and the company capability in pursuing a fast track approach to development projects.

The field is located in shallow waters 12 kilometers off the Mediterranean coast of Egypt in the Baltim South development lease. It lies 10km from the Nooros field, but still within the Great Nooros area. This is an area in which Eni first recognized great gas production potential and where it is conducting other new exploration projects. With the

Abu Sennan Transaction Update

start-up of the first well, BSW1, the field is now producing with an initial rate of 100 million standard cubic feet per day (scf/d) from a new offshore platform connected to the existing onshore Abu Madi Gas Plant through a new 44 km long, 26 inch diameter pipeline.

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ockhopper Exploration plc (RKH), the oil and gas exploration and production company with key interests in the North Falkland Basin, is pleased to provide the following progress update in relation to its previously announced disposal of Rockhopper Egypt Pty Limited to United Oil & Gas Plc (United).

At close of business on 3 October 2019, all the existing joint venture partners in the Abu Sennan concession had irrevocably and unconditionality waived their pre-emption rights under the Joint Operating Agreement.

The process to satisfy the remaining conditions precedent, including United shareholder approval, completion of the readmission of United to trading on AIM and receipt of Egyptian government approvals, are progressing well. The transaction remains on track to complete by the end of Q4 2019.

Egypt Seeks More Investments in Mining Sector

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gypt and two world companies discussed boosting cooperation in the mining domain.

This came in a meeting between Minister of Petroleum and Mineral Resources Tareq el Molla with Jeremy Crozier, President of Principle Verve International and Brian Rudd, CEO of Capital Drilling.

The meeting tackled investment opportunities after the amendments of the new mineral wealth law, especially since the two companies have a long history of nearly 30 years in the field of mineral exploration and mining industry in Europe, North America, Africa and Australia.

Molla reviewed Egypt›s geological advantages and its open mines, which can be operated throughout the year due to the existence of an infrastructure that helps and encourages mining work.

The heads of the two companies expressed their willingness to invest in the field of gold exploration in Egypt in light of the political and economic stability and future plans of the Ministry of Petroleum to develop the mining sector in Egypt.

The meeting was attended by Fekry Youssef, Petroleum Undersecretary for Mining and Geological Affairs and Osama Farouk, Chairman of the Mineral Resources Authority.

Petroleum Today - October 2019 13

Arab & International News

Britain set to receive two LNG tankers

Cyprus, Greece, Egypt call on Turkey to end ‹provocative› actions

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yprus, Greece and Egypt called on Turkey to “end its provocative actions” in the Eastern Mediterranean Sea, including exploring for oil in Cyprus’ territorial waters, which they called “a breach of international law”.

Turkey said it had sent a drilling ship to the area where Greek Cypriot authorities have already awarded hydrocarbon exploration rights to Italian and French companies.

“The Heads of State and Government expressed their grave concern over the current escalation within the maritime areas of the eastern part of the Mediterranean, condemning the continuing Turkish actions in the exclusive economic zone of Cyprus and its territorial waters, in violation of international law,” Cyprus, Greece and Egypt said.

A Saudi Aramco chief: attacks may continue without international response

14 Petroleum Today - October 2019

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ritain is set to receive liquefied natural gas (LNG) tanker Gaslog Savannah, with a capacity of 153,000 cubic metres, from the U.S. Cove Point facility on November 5.

LNG tanker Lijmiliya, with a capacity of 258,000 cubic metres, is due to arrive in Britain in October and is likely to load as it appears to be empty, Refinitive shiptracking data showed.

ttacks such as the one on Saudi oil facilities which sent oil prices up by as much 20% may continue if there is no concerted international response, Saudi Aramco’s Chief Executive Amin Nasser said “An absence of international resolve to take concrete action may embolden the attackers and indeed put the world’s energy security at greater risk,” he told the Oil & Money conference in London in rare political comments.

He added Aramco was on track to regain its maximum oil production capacity of 12 million barrels per day by the end of November.

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Thai energy ministry sets March target to resolve Chevron dispute

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hailand’s energy ministry said it had set a March target to resolve a $2 billion dispute with U.S. oil and gas major Chevron Corp and would make the “utmost effort” to reach a deal after the company halted arbitration.

The dispute resulted from a retroactive Thai law in 2016 requiring gas field operators to pay the costs of decommissioning assets they have installed even if they no longer operate them.

“This negotiation will require our utmost effort because it concerns national interests,” permanent-secretary Kulit Sombatsiri said.

“We have up to 180 days to work it out,” Kulit said, adding that the time frame was stipulated by law.

E

Exxon to make $500 mln initial investment in Mozambique LNG project

xxon Mobil plans to invest more than $500 million in the initial construction phase of its liquefied natural gas (LNG) project in Mozambique.

The U.S. oil company’s $30 billion Rovuma LNG project, jointly operated with Italy’s Eni, has a capacity of more than 15 million tonnes a year (mtpa) and is set pump much-needed cash into the southern African nation’s ailing economy.

“The Area 4 partners will advance midstream and upstream area project activities of more than $500 million as initial investments,” Exxon head of power and gas marketing Peter Clarke said.

Construction of onshore facilities has been awarded to a consortium led by Japan’s JGC, U.K firm TechnipFMC and U.S. company Fluor Corp.

“These EPC (engineering, procurement and construction) contracts cover the construction of two natural gas production trains with a total capacity of 15.2 million tons per annum, as well as associated onshore facilities,” Clarke said.

Final investment decisions, a term used by the oil industry to mean the commercial and regulatory aspects of a project are finalized, would be made in 2020, Clarke said.

Petrobras removes 133 tonnes of oil from Brazil,s beaches, CEO says

S

tate-run oil company Petroleo Brasileiro has collected 133 tonnes of oil along Brazil’s northeastern shoreline, Chief Executive Roberto Castello Branco said, in an unexplained mystery he said was worrying.

Speaking with lawmakers, he said the company had not identified any of its own oil in its analyses.

He also said that, in order to maintain stable production, Petrobras, as the company is known, needed new reserves of 1 billion barrels per year, at a cost of $3 billion.

16 Petroleum Today - October 2019

Corporate News

Rockwell Automation and Schlumberger Announce Closing of Sensia Joint Venture

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ensia, the oil and gas industry’s first digitally enabled, integrated automation solutions provider, will drive efficiency, optimize performance and reduce risk Rockwell Automation (NYSE: ROK) and Schlumberger (NYSE: SLB) announced the closing of their previouslyannounced joint venture, Sensia, the oil and gas industry’s first digitally enabled, integrated automation solutions provider.

The joint venture leverages Schlumberger’s deep oil and

gas domain knowledge and Rockwell Automation’s rich automation and information expertise to address this fastgrowing market.

“Sensia will make industrial-scale digitalization and seamless automation available to every oil and gas company so their assets can operate more productively and profitably,” said Allan Rentcome, Chief Executive Officer of Sensia. “It will make oil and gas production, transportation and processing simpler, safer, and more secure.”

Eni Announces New Production from the Western Desert Eni announces that production from South West Meleiha Development Lease, located in the Egyptian Western Desert, some 130 Km North of the oasis of Siwa, has started. The current production, delivered through two oil producer wells, is around 5.000 barrel of oil per day (BOPD) and is expected to reach 7.000 BOPD within September 2019. The oil is transported and treated at the Meleiha Plant facilities operated by AGIBA, a company equally held by IEOC and

the Egyptian General Petroleum Corporation (EGPC). South West Meleiha oil discoveries have been made in 2018, while other exploration wells are now planned to be drilled on the nearby prospects within the exploration area.

Eni, through its subsidiary IEOC, holds a 50% interest in South West Meleiha while EGPC holds the remaining 50%.

AGIBA is the operator.

Successful MSD-19 Well at West Gharib Concession in Egypt

S

DX Energy plc (SDX) is pleased to announce that the MSD-19 development well in the West Gharib Concession in Egypt (SDX 50% Working Interest & Joint Operator) has encountered a commercial oil accumulation.

The well was drilled to a total depth of 4,665 feet and

18 Petroleum Today - October 2019

encountered approximately 135 feet of net heavy oil pay across the Asl Formation, with an average porosity of 24%.

The well was completed as a producer, connected to the central processing facilities at Meseda and brought online at an average stabilised rate over five days of approximately 315 bbl/d (gross).

Wintershall Dea Committed to Egypt

I

n early 2018, Wintershall Dea announced the start of an extensive work program in all own-operated Egyptian assets. The company is currently investing more than 500 Million US-Dollars over three years (20182020-), aiming to significantly boost its gas and oil production in the country.

“We look back on very active 18 months in Egypt”, says Mario Mehren, CEO of Wintershall Dea. «We have already realized a good part of the upside potential in our ownoperated assets Disouq and in the Gulf of Suez. Furthermore, the West Nile Delta project is progressing towards completing the development of the five fields by end of this year.

These achievements are indicative of our lasting and sustainable commitment to Egypt», he adds. «We look forward to making further contributions to the development

of the Egyptian energy sector, supporting the country on its way to become an energy hub for the region.»

BP announces industry-first, continuous methane measurement programme

D

rones equipped with space-age sensors are part of a wave of advanced technology zooming into operation at BP’s new major oil and gas processing projects as part of a programme to continuously measure methane emissions.

The high-tech kit is part of an industry-leading BP programme to continuously detect, measure and enable the reduction of methane emissions at new and existing BP-operated Upstream assets. This crackdown on emissions has been made possible by a raft of new and complementary technologies.

Hady Meiser Egypt

H

ady Meiser Egypt for producing steel gratings is specialized in fabricating steel gratings (blackgalvanized) as well as steel stair steps which is also made with gratings by press welding according to DIN 24537 & 24531 and ISO 1461 & ASTM A 123 . All specification is according to the shown onto our catalogue and dimensions are according to client›s inquiries.

Mr. Eslam Abdel-Hady CEO

Address :ElShrouk Industrial Zone – Khanka – Kaiobia Contacts : 01001726068 -01144877633 - 0127 679 8800 – 01001726135 Fax : +2 02 44698047 – 44698212- 44604123 E-mail :trabia.meiser@gmail.com trabia_meiser@hadymeiser.com

20 Petroleum Today - October 2019

Mr. Taha Abo Rabia General Manager

Talent & Technology

Electro-mechanical downhole cutting technology

[ Fig-1 Halliburton Electro-mechanical downhole cutting tools ]

H

alliburton Company has announced an asset acquisition of a new portfolio of electro-mechanical downhole cutting tools and tubing punches from Westerton (UK) Ltd. These services provide operators with a safe and reliable alternative to traditional pipe recovery and intervention across the well lifecycle from exploration to abandonment.

The electro-mechanical downhole cutting portfolio includes single and rotating blade configurations that perform precision cuts on oilfield tubulars. Operators can achieve single blade cuts in less than two minutes with real time downhole data that reduces uncertainty.

This new technology eliminates the need for traditional explosive charges and chemicals, resulting in improved safety and easier transportation. Each cutting operation requires minimal surface equipment to enable faster deployment from any wireline unit.

“The ability to deploy cutting services rapidly and efficiently is important for pipe recovery,” said Trey Clark, vice president of Wireline and Perforating. “This new technology complements Halliburton’s extensive well intervention portfolio, helping operators reduce the cost to construct new wells and extend the life of old wells.”

On a recent campaign in the North Sea, an operator utilised the electro-mechanical downhole cutting service for a well abandonment program. The technology successfully saved one and half days of rig time per well – a substantial reduction from the initial plan.

Monitoring Pressure in Applications with Vibration and Pulsation

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iquid-filled gauges have several drawbacks that can introduce unnecessary elements of risk into a work environment. The issues associated with liquid-filled gauges can now be overcome with a new product solution that can be applied in all applications with vibration and pulsation, without the restrictions associated with liquid filling.

One of the initial challenges that arose in monitoring pressure with dry gauges was caused by applications with vibration and pulsation. It was difficult to measure pressure in these types of applications as the pressure gauge pointer would shake making it impossible to get an accurate reading.

Liquid-filling pressure gauges became the common method for steadying the pointer of a gauge in vibrating and pulsating applications. By filling the gauge case with a liquid, the movement of the gauge was dampened preventing the pointer

22 Petroleum Today - October 2019

from shaking. Liquid-filling has been the primary way of dealing with vibration up until today.

While adding liquid to a gauge allows operators to accurately monitor the pressure of a process, it has limitations on where it can be installed compared to a dry gauge. In addition, liquid-filed gauges have several drawbacks that can introduce unnecessary elements of risk to a work environment.

The challenges associated with liquid-filled gauges can now be overcome with a new product solution that can be applied in applications with vibration and pulsation without the limitations. Winters’ StabiliZR™ pressure gauges are dry gauges that can be installed in applications where liquidfilled gauges have traditionally been installed. The reason for StabiliZR’s effectiveness where other dry gauges fail is the StabiliZR™ movement which provides pointer dampening without requiring the entire case to be filled with liquid.

Connector Subsea Solutions acquires Hydratight’s MORGRIP business

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[ Fig- 5 MORGRIP subsea pipeline repair connector ]

ipeline repair connectors are critical components in the repair of oil and gas pipelines. The operator’s requirements for this type of equipment are extremely high as the consequences of failure are dramatic with regards to potential environmental and commercial impacts and even to a region’s overall energy supply. MORGRIP Connectors boast a 100% leak free in-service track record of over 30 years.

Hydratight’s MORGRIP business has a reference list second to none with more than 3,000 connectors delivered to the global oil and gas industry. MORGRIP’s offer a unique, robust, field proven, durable design that meets all of the industry’s strictest qualifications. This makes MORGRIP the primary choice of connector for the repair of critical pipelines and is in use by most of the major operators.

The MORGRIP connector has also proven to be the connector of choice for emergency pipeline repair systems (EPRS) worldwide and through the acquisition; CSS takes a lead position providing emergency pipeline repair for more than 300 high value pipelines.

The acquisition of the MORGRIP business completes CSS’ products and service offering enabling CSS to take a lead role in providing complete subsea and deepwater pipeline repair solutions, delivering it’s services on a sale or rental basis worldwide.

“This has been a strategic move to build a foothold in a market that we believe will grow significantly the next few years. With the MORGRIP Connector and the MORGRIP team onboard we have taken a position to meet client’s requirements for the effective execution of demanding deepwater pipeline repair projects,” said Pål Magne Hisdal, chairman of CSS.

Petroleum Today - October 2019 23

Chevron Technology Ventures pitches in on Well Conveyor development The Conveyor has been optimized for running on batteries, with an efficient electro-mechanical design, allowing for extended tractoring distances of more than 15,000 feet. Not being dependent on power and communication from the surface allows operators greater flexibility and lower priced conveyance alternatives. The Conveyor has been designed for simplified operations and reduced maintenance, enabling the service to be provided by the regular wireline / conveyance providers. This translates into less interfacing and manpower being needed for operations.

Well Conveyor was founded in 2015 by Kenneth Fuglestad to pursue the development of a novel downhole tractor that would be more cost-effective, slimmer, simpler to operate and more power efficient than existing offerings, allowing for the utilization of downhole battery power. Early support came from angel investors, the Research Council of Norway and Innovation

Norway, which took the company through the concept, feasibility and early development phases for the Conveyor.

ProVenture and Investinor invested in the company early 2018, and Chevron Technology Ventures (CTV) invited Well Conveyor to participate in its Catalyst Program.

CTV’s Catalyst Program was created to support early-stage companies advancing cutting-edge technologies that can directly benefit the oil and gas industry. These relationships provided the means to advance the development and qualification phases and to expand the organization.

Well Conveyor has carried out extensive in-house qualification testing of the technology and is now preparing for first field trials in the US. The patented Slim Batterypowered Conveyor will serve as a platform for additional innovative and cost-effective conveyance solutions to be developed by the company.

Probe releases new calliper for geothermal well operations

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robe has launched its UHT Dimension XY Caliper, the first XY Caliper Tool specifically designed to operate in ultra-high temperature environments.

This new development expands upon the renowned Kuster® geothermal logging tool portfolio, used extensively in the global geothermal industry for its performance and reliability.

Developed to operate in hostile environments up to 325°C (617°F), the UHT Dimension tool provides two continuous independent perpendicular measurements (X and Y) of the internal diameter of the casing. The tool also produces a highresolution temperature profile of the well via an external fastresponse resistance temperature detector (RTD). There is no other caliper tool that offers this versatility for ultra-high temperature and geothermal well operations.

“The introduction of ultra-high temperature XY Caliper technology for the geothermal industry is a major breakthrough. A critical factor is that mineral deposition regularly affects geothermal well conditions. Until now, gauging the internal diameter of these wells was ineffective.

The ability to generate a continuous log and accurately calculate flowrates is huge differentiating advantage,” said Steve Beattie, Sales Manager for Well Monitoring for Probe.

24 Petroleum Today - October 2019

“By gathering accurate, reliable on-depth casing dimensions, geothermal companies can quantify scale build-up and any other restrictions due to [ Fig-3 UHT first XY Caliper Tool ] the reduction in casing diameter. The tool also identifies downhole components and other anomalies. By detecting such issues early on, the operator engaging in such proactive maintenance can maintain a critical flowrate by removing the restriction; which will aid in reducing the operational downtime and treatment cost.”

The UHT Dimension tool is very versatile. It can be run stand-alone or combined with other Kuster geothermal PT and PTS tools. Its robust mechanical design features single roller arms that conform easily to most wellbore conditions.

However, if there is a need to run over slotted sleeves or sandscreens, an optional triple roller arm is available for increased run efficiency.

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MEDITERRANEAN LNG MARKET EVOLUTION

The transformation of global and regional LNG trade over the last twenty years has been a story of rapid growth, change and increased flexibility in LNG cargo movements. Asia continues to predominate global LNG trade, but the European LNG market has promoted significantly in the past decade and seems destined for sustained growth and change over the next decade or so. Despite the LNG import market in North America being overwhelmed by unconventional gas developments in the last few years, future sustained development of LNG demand in Asia and Europe are enhanced by firm new project commitments.

28 Petroleum Today - October 2019

cord, reaching 316.5 million tonnes (MT). This marks an increase of 28.2 MT from 2017, equating to 9.8% yearon-year (YOY) growth. The continued growth in trade was supported by increases in LNG output from liquefaction plants ramping-up and coming online, more than offsetting lower production from several legacy projects.

Australia led all exporters in gradual growth (+12.2 MT), supported by the Wheatstone LNG and Ichthys LNG projects. The United States was again the second-biggest driver of LNG supply growth, adding 8.2 MT as trains at Sabine Pass LNG operated for the full year and Cove Point LNG came online. Asia continued to be the driver of international LNG demand growth, as China broke its own record for gradual LNG by importing an additional 15.8 MT in 2018. This was driven by the powerful enforcement of environmental policies prepared for promoting coal-to-gas switching as well as continuing economic growth. Other key markets that lead global LNG growth included India, South Korea, and Pakistan, which took in a combined 12.8 MT of incremental imports. The Pacific Basin continues being the key driver of trade growth, with intra-Pacific trade flows reaching a record 134.2 MT, confirmed by Australian production and Chinese demand.

A number of North American LNG export projects are progressing to supply this growing market demand in Europe and Asia. Unprecedented gas discoveries in deep-water offshore Eastern Mediterranean and East Africa are also likely to compete for LNG market share in growing Asian and European gas markets. The regional statistics reveal the complexity of commercial, political and technical drivers at play, particularly in the case of Europe, and how these drivers are collaborating to boost future demand for LNG. State of the LNG Industry and Global Trade For the fifth successive year, global LNG trade set a re-

East Med Gas Potentials Massive gas reserves are considered the game changers in the East Med. The three big finds of that period – Egypt’s offshore Zohr field, with reserves of 21.5trn cu feet of gas; the Israeli offshore Tamar and Leviathan fields, with 11trn cu feet and 22trn cu feet of reserves, respectively; and the 8trn-cu-feet Aphrodite find off the coast of Cyprus – have the prospect to transform the .region’s energy landscape In Egypt, the Zohr Progress by ENI, among others, has led to a revival in gas production: output grew from a low of 3.9bn cu feet per day in 2016 to 6.65bn in February 2019. For Israel and Cyprus, the gas discoveries assure greater energy security and new export revenues.

A group of other fields have also been and are starting .to be developed, notably in Cyprus more recently Mediterranean Gas Infrastructure and Liquefaction Plants On 16thApril 2019, on the occasion of the Mediterranean Gas Infrastructure Operator (MedGio), organized by the Egyptian Natural Gas Company, Eng. Tarek El Molla, Minister of Petroleum and Mineral Resources,

Petroleum Today - October 2019 29

delivered a speech, in which he assured that the Mediterranean region holds a significant importance in the world order politically, economically and geographically.

It is gaining major significance over the coming years, in the light of the existence of abundant gas resources, due to the big discoveries especially in the Eastern Mediterranean Region. El Molla assured that cooperation among the Mediterranean countries, members of MedGio, will consolidate the available infrastructure, in the light of the growing strategic importance, for the security of energy supply, in which the gas represents a fundamental role towards cleaner energy system.

Compared to other countries on the Mediterranean, Egypt’s gas infrastructure is more developed. It has a relatively large natural gas export infrastructure, but is underutilized. With a total length of 7,485 km of transmission grid and 38,000 km of distribution grid, Egypt has the biggest infrastructure in the East Mediterranean area. Connecting the Mediterranean discoveries to Egyptian infrastructure necessitate ultimately lower in-

30 Petroleum Today - October 2019

vestment than the construction of Greenfield LNG facilities in Cyprus or Israel. The Egyptian option is beneficial to all parties involved and enhances the role of Egypt in the region and its ability to secure revenue from being a transit route and re-operating the two LNG plants.

Global liquefaction capacity still in the widespread phase of build-out that began in 2016, driven largely by capacity additions in Australia, the United States, and Russia. Between January 2018 and February 2019, 36.2 million tonnes per annum (MTPA) of liquefaction capacity was added.

In September 2018, Egypt signed an agreement with Cyprus to connect Aphrodite gas field to its liquefaction plants in Idku and Damietta, whereby Cypriot gas would reach Egypt via a marine pipeline to be liquefied and re-exported. Also, $15 billion worth of gas from Israel’s Tamar and Leviathan fields will be processed in Egypt as part of a 10-year deal between the Israeli Delek Drilling Company and the Egyptian Dolphinus holding company. Existing LNG terminals on the two branches

of Nile Delta provide Egypt with an edge as a transit point for gas coming from Cyprus and Israel. The two plants are capable of exporting 1.8 BCFD, providing a platform to handle the combined production of both Leviathan and Aphrodite gas fields.

Egypt’s strategic location and an infrastructure including refineries, liquefaction plants and petrochemical factories, poises it to become an important trading and distribution center for natural gas. This is a boost to Egypt’s international standing to grow reliance on natural gas, especially from Europe. EU gas demand is rated to range at around 400 billion cubic meters per year. Currently, Russia and Norway are considered the leading suppliers to the EU. Regional Integration between East Med Countries A series of major natural gas discoveries made in recent years and the prospect of substantial hydrocarbons resources waiting to be tapped beneath the Eastern Mediterranean waters have sparked major international interest. If developed in a successful way, they may significantly alter the energy picture in the Mediterranean region. They may also be a force that enhances energy security, economic evolution and regional cooperation.

If not, they might become a major component of the geopolitical struggle, fuel existing disputes and add to the various anxieties in the region and beyond.

Egypt’s Steps towards Regional Integration Egypt is in a strategic location and proximate to the gas

resources-rich countries, which helps it to take steps towards regional integration. Egypt Initiated a strategic dialogue with the EU on energy and Signed a Memorandum of Understanding on an Egypt-EU Strategic Energy Partnership (April 2018). It signed an agreement with Cyprus to establish a natural gas subsea pipeline between the two countries, in order to facilitate natural gas delivery from Cyprus to Egypt’s liquefaction plants in Idku and Damietta. (September 2018). With Jordan, both countries signed MoUs between natural gas companies to regulate the sale and purchase of natural gas (January 2019). Also, it signed an MoU with Iraq and Jordan to transport Iraqi natural gas and crude oil to Egypt via Jordan.

The discovery of hydrocarbon resources presents an exceptional window of opportunity for regional cooperation, and long term energy security. Exploitation and transportation of these resources in a timely and effective way could pave the way for minimizing the time-tomarket and boost the access to more valuable markets.

Influential cooperation between the different countries and the energy companies active in the area could result in “optimal” investment decisions, such as the development of joint export infrastructure for fields located in various countries. As mentioned by Amos J Hochstein, US former Special Envoy for International Energy Affairs, countries will save billions if they share infrastructure and market access. If they don’t share those resources, most of the gas will have to stay in the ground.

Petroleum Today - October 2019 31

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Technology Applications

Performance and Cost Benefits of Environmental Drilling Technologies:

A Business Case for Environmental Solutions By: Lydia Brantley, Jennifer Kent, Natalie Wagner, SPE, National Oilwell Varco

A

bstract

Environmental impact has become business critical as we have been unable to crack certain issues to the degree expected for our industry. It is the central challenge for the continued development of shale markets, as it has been offshore. In a customer survey completed in the first quarter of 2012, a diverse group of operators, drilling contractors, and service companies identified their top three challenges for shale development: pricing, inexperienced personnel, and—of paramount importance—environmental impact.

The industry recognizes the need for reduced environmental impact, but what do we need to achieve it?

In the aforementioned survey, many operators and drilling contractors expressed looking to oilfield service and supply companies for continued innovation with the expectation that they continue to be to be forward-thinking and present ideas that provide value. The industry has two primary means for reducing environmental impact of its operations: processes (operator and contractor-driven) and equipment (service and supply-driven). This paper proposes that the two must work hand-in-hand. It explores the opportunity to take this further: identifying critical steps such as process design for reduced environmental impact with lower-impact technology and industrial engineering. The dual approach is needed to affect large-scale change.

This paper will examine the positive impact of the implementation of select environmental technology can have on oilfield economics from the perspective of an oilfield equipment, technology, and services provider. It aims to: Ó Demonstrate a case for environmental solutions

Ó Establish the importance of improved environmental

34 Petroleum Today - October 2019

performance for market access Ó Identify areas in which operators evaluate environmental impact Ó Discuss the technology opportunities available to operators Ó Recognize and quantify the performance and cost benefits of aforementioned technologies.

The Positive Impact of Environmental Technologies on Oilfield Economics

Easy oil is gone. The aging of the conventional reservoir base, evident in the dearth of conventional green fields, acceleration of production decline rates, and limitations on spare capacity, combined with increasingly restricted reserve access following the wide reassertion of state control over national petroleum resources worldwide has driven operators to pursue higher-risk/higher-cost projects in order to replace reserves and maintain attractive assets.

Along with the technical and economic challenges of these projects, operators now have to manage new challenges associated with drilling in areas that are more socially sensitive areas (e.g. northeast US, continental Europe, and Australia) and environmentally sensitive (e.g. the Arctic).

Mitigating environmental impact has become business critical—both on land and offshore—as we have yet to effectively address certain issues to the degree expected for our industry.

It would be naïve to think that regulations will drive improvement in our industry. Economics drive technology, and technology drives change. The oil and gas industry constantly seeks new ways to drill better, faster, and safer. Like any industry, oil and gas strives to do so while

increasing performance and reducing direct and associated costs; yet unlike many others, oil and gas faces the additional challenge of managing and mitigating the environmental impact of its operations. Our actions are magnified in part due to the areas in which we operate, and our missteps can have a significant impact on local communities and the environment. Engineering and industrial controls should be used together to achieve parallel goals of increased performance and reduced environmental impact. By aligning the right people, processes, equipment, and technology, we can do more.

Increasing operational performance and reducing environmental impact do not have to be mutually exclusive (Harvard Business Review 2006). Admittedly, there are reasons why this perception exists. In some instances, environmental regulations have contributed to lower rates of return for oilfield players. For example, emission control regulations for new non-road diesel engines (i.e. the US and Europe’s respective Tier 4 Interim/Stage IIIB and Tier 4 Final/Stage IV) have forced oilfield equipment manufacturers and technology providers to pursue costintensive technology development and engineering. While some companies have taken advantage of the opportunity to establish a competitive advantage in these fields, the transition has been demanding in terms of resources, both financial and otherwise.

This paper examines the positive impact that the implementation of select environmental technology can have on the economics of the oilfield. Across the industry, the main focus areas for improved environmental performance involve: energy efficiency and emissions, water use and recycling, leak prevention and spill containment, and drilling waste management. Acknowledging that the implementation of processes and technologies needed to mitigate the environmental impact of oil and gas drilling will be a longterm process achieved through incremental goals, this paper will concentrate primarily on the possibilities for improved environmental performance matched with operational and efficiency gains in one area: drilling waste management.

Drill Cuttings: An Introductory Definition

The largest source of drilling waste, drill cuttings present a significant challenge both on land and offshore as their presence, treatment, and disposal can inhibit the operational and economic efficiency of a drilling program. Drill cuttings refer to the materials (mainly solids plus some residual fluids) removed from the wellbore during drilling operations.

Drilling fluid circulated through the wellbore and annular space during drilling carries the cuttings out of the wellbore and out to the surface. There the cuttings are separated and disposed: either discharged, re-injected, or (in the case of

offshore wells) shipped to land-based treatment facilities (Oil & Gas UK 2012).

While cost plays a role in determining the disposal option, environmental laws and regulation limit options based on the drilling location as well as the type of drilling fluid used.

Cuttings generated from wells drilled with oil-based mud, for example, must be treated extensively prior to disposal (as compared to those generated from wells drilled with water-based mud). Treatment vis-à -vis technologies like centrifugal dryers and thermal desorption units can limit the environmental risks associated with disposal both on land and offshore. Processes and technologies that reduce the amount of drill cuttings and/or treatment required before disposal can deliver operational and economic benefits while mitigating environmental impact, proving: what’s good for business can also be good for the environment.

Waste Management Helps Enable Market Access

With the increase of drilling in more technically challenging operating environments, environmental performance has become business critical as we have been unable to resolve certain issues to the degree expected for our industry.

Improved waste management enables market access, particularly in environmentally and socially sensitive areas.

Compliance with environmental laws and preservation of positive public opinion play a role in market access. While the conversation below focuses on waste management, the same general ideas are transferrable to the other major focus areas for improving environmental performance in the oil and gas industry.

Compliance with Environmental Laws and Regulations

The way in which environmental risks are perceived and regulated can impact the support for and development of drilling in certain areas. Regulations have barred drilling in areas rich in resource potential at various times due to political and public concerns of environmental impact. For example, various countries controlling Arctic access declared a temporary moratorium on drilling following 2010s Gulf of Mexico oil spill due to concerns that current infrastructure for spill cleanup was inadequate (Bolstad 2010). Similarly, multiple countries with technically recoverable shale gas resources (e.g. France and Bulgaria) have placed a temporary moratorium on the hydraulic fracturing necessary for shale gas development pending further environmental investigation (Jacobs 2012). Certain areas of the US are banning the practice following recently passed ballot amendments (Associated Press 2012). The aforementioned may be extreme examples, but they demonstrate the business

Petroleum Today - October 2019 35

importance of managing environmental performance throughout the entire drilling and completions process.

Reducing the presence and/or environmental impact of drill cuttings may be essential for obtaining market access, complying with regulations, and avoiding possible remediation costs. Complying with environmental laws and regulations is business critical as non-compliance may result in either the inability to drill or substantial fines.

Regulatory controls minimize the impact of permitted discharge of cuttings based primarily on toxicity. Laws and regulations vary by location. On US land, for example, waste requirements typically originate at the state level for oil and gas exploration and production while the Environmental Protection Agency is the primary regulatory agency for environmental concerns (API 2011). In addition, many of the local watersheds and ground water protection agencies are either at a multi-state level or a river basin level (EPA 2012). Offshore, national government agencies regulate the permitted discharge of cuttings to prevent unreasonable degradation of the marine environment. Depending on the drilling location, the target level of non-aqueous fluids on cuttings typically ranges from 0% to 8%. In recent years, regulations governing the treatment and disposal of drill cuttings have become more stringent with multiple areas moving towards complete zero discharge (Figure 1).

Maintaining Social License to Drill

The rising power of local community stakeholders— particularly in US land, where individual landowners maintain subsoil ownership rights—may have greater impact on our industry today than ever before. Now, the ability to conduct oil and gas drilling is subject to opinions of outside parties in addition to environmental laws and regulation.

In today’s technology-driven world, everyone has access to information. Traditional news outlets are no longer the sole opinion leaders. Everyone has the ability to create and disseminate information, fact-based or not. In some cases, this can contribute to more entrenched environmental opposition, especially in ecologically and socially sensitive areas like those described above. How environmental risks are perceived and regulated has impacted access to oil and gas reserves worldwide. Today, public opinion helps determine the ability to obtain and maintain drilling permits.

A company that is not conscientious of its environmental impact and/or working to mitigate may be subject to losing its social license to drill (Kitasei 2011).

Technologies Delivering Operational and Cost Benefits Along with Improved Environmental Performance A central challenge surrounding the implementation of select

36 Petroleum Today - October 2019

environmental technologies is ensuring efforts to reduce the environmental impact intrinsic in oil and gas development do not negatively impact operational and cost performance.

For waste management, technologies that reduce the amount of drill cuttings and/or treatment required before disposal achieve this balance. The technologies discussed below demonstrate how business and environmental goals can be achieved in parallel, proving that technology decisions made on the basis of performance and bottom-line dollars can also deliver legitimate environmental gains.

Drilling Tools for Wellbore Stabilization Reduce Amount of Cuttings Generated While Drilling

When a drill bit deviates from the desired well path, drillers must reduce the pressure applied to the drill bit and make frequent adjustments to the bottom hole assembly (BHA) to steer the bit back to the desired course. These corrective actions consume valuable drilling time and result in crooked oversized wellbores for drilling efficiency losses estimated as high as 200%. Through the use of rotary steerable systems and similar low-cost alternatives, drillers can maintain verticality in the wellbore and recover the lost time and cost. They can also reduce the amount of environmental waste by an estimated 30% through decreased cuttings and fuel consumption. Therefore, along with well-accepted efficiency gains, drilling straighter wells delivers positive environmental impact by reducing drilling waste from the source.

Centrifuges and Dryers Reduce Presence of Non-Aqueous Fluids on Cuttings

Drilling fluid type and local discharge requirements (in terms of the permitted level of non-aqueous fluids on cuttings) help determine the method for cuttings disposal offshore. For cuttings with non-aqueous fluids, the main options include: Ó Cuttings re-injection into existing or new wells Ó Shipping cuttings onshore for treatment and disposal Ó Offshore discharge following treatment (Tullow Oil 2009).

While cuttings re-injection and shipment are the preferred methods for zero discharge environments, in environments where offshore discharge is allowed centrifuges and dryers offer operational and cost efficiencies along with environmental performance. Centrifuges separate fine drilled solids from the drilling fluid. Doing so prevents drilled solids volume from exceeding a threshold level in the drilling fluid that could inhibit the drilling process and/ or damage additional rig equipment. When drilled solids increase above the acceptable threshold level, the only way to reduce the solids to fluid ratio to acceptable levels involves dumping and diluting the fluid.

Generally, the desired ratio between drilling fluids and drilled solids is 95:5. Therefore, for every barrel of drilled solids a centrifuge removes, it eliminates the need for ~19 supplemental barrels of drilling fluid. Using a centrifuge eliminates the costs associated with adding extra base fluid (estimated at USD 2500 for 19 barrels) as well as treating the increased volume of produced waste. The use of dryers further eliminates cost by returning base fluid back into the mud system for re-use.

Centrifuges can be considered an environmental tool, as demonstrated by the above example. Proper waste management begins with shale shakers. Improved and automated shakers increase the efficiency with which solids are removed from the drilling fluid, leading to better reuse and fewer requirements for additions for time and cost savings (El Dorry 2012). However, one operator explained that, on average, centrifugal dryers offered a 65% reduction in the amount of barrels of cuttings discharged over shale shakers alone (Figure 2).

Enhanced Water-Based Mud Delivers More than Environmental Benefits

Drilling with water-based mud eliminates the more environmentally damaging side effects of oil-based mud: no hydrocarbons and no chlorides that require treatment prior to proper disposal. Oil-based mud remains popular for land applications because of its consistent performance. New drilling fluid technologies offering improved environmental performance as a primary benefit must also deliver bottomline operational and cost gains. An oil and gas equipment manufacturer developed an enhanced water-based mud that does just that: matching oil-based mud’s performance in days versus measured depth and cost.

Proven on land and inland waters, the enhanced water-based mud has proven to be as fast as oil-based mud. For a sample of wells with a total vertical depth of 12,500 feet to 14,000 feet, drilling with oil-based mud took an average of 15.9 days to complete while enhanced water-based mud took 15.8 days. It has also matched performance in ways other than days versus measured depth. One operator in the Eagle Ford Shale in south Texas, US has used the enhanced waterbased mud on 43 wells. Each was drilled with no stuck pipe and casing reached bottom. Enhanced water-based mud also offers an improved lubricity coefficient over traditional water-based mud. Whereas water-based mud has a lubricity coefficient of 0.28, the enhanced water-based mud has 0.14 which results in improved penetration rates, consistent reduction of lost circulation and delivery of stable wellbore.

Enhanced water-based mud matches oil-based mud performance without the increased disposal cost typically associated with non-aqueous fluids. Upfront costs for

38 Petroleum Today - October 2019

enhanced water based mud is higher, with an operator in the Eagle Ford reporting a cost of USD 150,000 compared to an USD 85,000 cost for oil-based mud. However, associated costs for oil-based mud add up quickly, notably the cost for the required base oil (Figure 3). Operators may spend nearly as much on diesel as they are on oil-based mud, ranging from USD 50,000 to USD 70,000 according to one operator.

Additional savings associated with disposal costs include additional equipment rental, rig cleaning, oil-based mud and base oil trucking, and cement slurry to surface for oil-based mud recovery.

In the Eagle Ford, an operator saved USD 300,000 per well using enhanced water-based mud. The operator reported a total savings of USD 12.9 million over 43 wells. In areas where leasing requirements forbid landforming cuttings and/or require cuttings to be disposed offsite the savings are less substantial. Nonetheless, the cost of enhanced waterbased mud is comparable to the combined cost of oil-based mud and necessary diesel.

Market Acceptance of Environmental Technology Related to Operation’s Economics

The market acceptance of technologies that improve environmental performance is directly tied to the operational and/or cost efficiency gains they also deliver. Consideration of environmental impact, while important for market access in terms of compliance with laws and regulatory and maintaining social license to drill, will only become commonplace should the technologies offered meet the operational and/or cost demands of standard drilling operations. One of the challenges oilfield service and supply companies face is addressing the environmental gains offered by some of their more traditional products. The root cause of this challenge is the lack of common metrics for evaluating environmental performance. Nonetheless, across the industry operators, drilling contractors, and service and supply companies have identified the main focus areas for improvement: energy efficiency and emissions, water use and recycling, leak prevention and spill containment, and drilling waste management.

Considering these areas, oilfield service and supply companies can begin preliminary evaluations of their existing product portfolio and market added benefits. Taking the next step of creating and incorporating a standard method for assessing environmental performance of technologies requires industry-wide support. The challenge of demonstrating the positive economic impact of the implementation of select environmental technologies cannot be resolved by one company alone; it will require the collective commitment and collaboration of all industry players.

Acknowledgements

The authors would like to thank David Reid, Tom Yost, Federico Mezzatesta, Khaled El Dorry, Garry McCraw, Mike Usher, Scott Jackson, Carl Tolbert, and Joe Blanc of National Oilwell Varco for their contribution of expertise and support.

REFERENCES API. 2011. Environmental Regulation of the Exploration and Production Industry.

Associated Press. 2012. Vt. Becomes first state to ban hydraulic fracturing.

Bolstad, Erika. 2010. McClatchy Newspapers. Arctic drilling still a no-go, despite judge’s moratorium ruling.

El Dorry, Khaled and Bill Dufilho. 2012. Automation Improves Shaker Performance. SPE 151180-MS. Environmental Protection Agency. 2012. Ocean Discharge Criteria Evaluation.

ExxonMobil.2012. Environmental Drilling Initiatives.

Harvard Business Review. 2006. Strategy and Society: The Link Between Competitive Advantage and Corporate Social Responsibility.

Jacobs, Justin. 2012. Petroleum Economist. Bulgaria joins France in fracking ban.

Kitasei, Saya. 2011. World Watch Institute: Vision for a Sustainable World.

License to Drill? Revised Study from New York Department of Environmental Conservation Outlines Conditions for Permitting Shale Drilling- but Not in Unfiltered City Watersheds.

Neff, Jerry. 2010. Neff & Associates. Fate and Effects of Water Based Drilling Muds and Cuttings in Cold Water Environments.

Oil & Gas UK. Knowledge Centre: Drill Cuttings.

Railroad Commission of Texas. Surface Waste Management Manual.

Reddoch, Jeff. 2008. World Oil. Why cuttings reinjection doesn’t work everywhere—Or does it?

Tullow Oil. 2009. Summary of Development Drilling Impacts and Assessment of Drill Cuttings Disposal Options.

Fig. 1—Environmental discharge requirements

Petroleum Today - October 2019 39

Fig. 2—Relative drill cuttings discharge by equipment type

Fig. 3—Cost savings offered by enhanced water-based mud

40 Petroleum Today - October 2019

H350 a multipurpose masterpiece for all business needs in Egyptian market

WHATEVER YOU WANT. EQUIPPED WITH WHATEVER YOU NEED Egyptian international motors (EIM) the sole agent for Hyundai commercial vehicles in Egypt. Introduces newest member of Korean giant family Hyundai H 350 in Egyptian market, a multipurpose vehicle that suits all business and commercial needs.

H350 The H350 is a reliable and efficient partner that gives your business a real advantage. It’s impressively well equipped with features that are designed to save you time and money.

Active ECO drive mode, for example, improves fuel efficiency and is now standard across the entire range.

Clever interior layout and packaging creates a ‘Mobile office’, designed to ease the driver’s daily task. For maximum practicality, there are up to 25 storage compartments around the cab.

H350 is classified into two applications: Bus and van. Moreover, it can be customized such as overall lengths, overall heights, and door locations. H350’s infinite transformation still continues.

H350 Bus application EIM & Hyundai offer a business class comfort on the road, with various seating layout starting from 14+1 seats up to 29+1 seats in addition to luxurious limousine application.

The refined interior design reflects the latest design trends achieving elegant and classy interior space for passengers.

LED overhead lighting is precise without being harsh, a sliding door or the front passenger door with inbuilt step makes entry easy and the hand rails are in the right place.

42 Petroleum Today - October 2019

There is even a sophisticated 8 speaker sound system that brings clear sound to every seat. Flush fitted side windows and specially developed air conditioning help ensure the perfect interior climate.

H350 Van application Whatever you need to move, wherever you need to take it, H350 delivers. The design philosophy for H350 van application makes it durable and operational efficient as the loading or unloading of H350 is easy work thanks to the short distance from the ground to the cargo deck. Load space between the rear wheel arches has not compromised thus maximizing cargo hauling capacity and convenience.

H 350 can be in different applications as, -Ambulance -Cargo van -Maintenance vehicle -Refrigerated -Mobile office -Double cab -Prisoner transportation

H350 Ambulance application In cooperation with one of the biggest companies in petroleum sector, EIM succeeded in 2019 to supply Gulf of Suez petroleum Co. (GUPCO) with two H350 ambulance application vehicles equipped with all needed equipment that serves the hard and dangerous business locations the company operates in.

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EIM exclusively has been distributing and serving more than 28 world reowned brands in more than 9 business sectors in the region operated through 2000 EIM business experts .Group activities include; multinational enterprise representation, after sales activities and free zone storage and clearance.

Technology Applications Well control Safety and Regulations on Deep Water and Onshore wells

By: Prof. Dr. Ahmed. Nooh - Eng. Mohamed Safan

W

ell control has always been

process.

a very important issue in the

We have many important points which can be very improved

oil and gas industry because it involves enormous amount of money, people’s safety, and

environmental issues. Well- control fundamentals have been understood and taught for almost half a century, but still well control problems and blowouts occur in the industry.

Substantially, all blowouts are related to human failure and error relative to well operations.

Early acknowledgment of a kick and fast close in are the keys to successful well control. Well control consider as a very sensitive and a systematic process. It is a team work and it requires a complete dedication to the job from each member of the team. A large portion of the blowouts are caused by either human error or equipment failure. Human mistakes are generally a result of the lack of regard, ignorance and miscommunication between the workers. Equipment

to make sure a safe drilling process. Human mistakes and equipment failures are the primary driver of the blowouts in an oil and gas well drilling process, as exhibited in the BP, 2010 and a well in Western Desert, Egypt. This contemplate infers that drilling mud is the essential obstruction to prevent hydrocarbons from going into the wellbore thus a cautious checking of the well is critical. It is the first obligation of the apparatus group to ensure that the thickness of the drilling fluid is more than the thickness of the reservoir fluid. Ó This study about accentuate that the rig crew should ensure that there are sufficient barriers in the wellbore to control oil from going into the wellbore. For instance separated from the drilling mud there ought to be blowout avoidance equipment introduced at the wellhead to seal the well if kick happens.

failure can likewise be a piece of human ignorance. On the

Ó Blowout prevention (BOP) equipment at the wellhead go

off chance that the objective is a protected and effective

about as an optional obstruction amid kick circumstances

drilling procedure then each and every detail ought to be

via fixing admirably from the wellhead. A watchful

considered and ought to be sufficiently given consideration

checking and testing of the Bow out preventer equipment

from the administration. An entire coordination between

previously and amid drilling process is vital. As showed in

the workers is obligatory and a far reaching and dependable

the BP contextual analysis that Macondo BOP system was

communication system is a fundamental piece of drilling

not tried and checked for extensive stretch of time.

Petroleum Today - October 2019 45

Ó If possible companies ought to introduce two blind shear

continuing the drilling. The choices how to stop the lost

rams (BSR) in BOP system on the off chance that on the

circulations destinations ought not be deferred as occurred

off chance that one neglects to seal the well amid crisis

in the Egyptian well blowout, it enabled hydrocarbons to

The accident of the April 20, 2010 involved a well integrity

movement a significant separation up to the wellbore. Ó Driller,s and Engineering method are generally utilized

failure, followed by a loss of hydrostatic control of the well.

as a part of the business to circle out the influx of

This was followed by a failure to control the flow from the

hydrocarbons from the wellbore after a fruitful well closed

well with the BOP equipment. The following are few main

«shut in» in case of kick circumstances.

circulation there is another accessible as a backup.

key findings relating to the casual chain of events, a better performance in the respective areas could have saved this

Ó The comparison between these two wells shows that: Engineering method is more efficient than Driller method

catastrophic incident from happening.

as its kill the well in less time but its need more drilling

1. The negative pressure test results were accepted

training for the rig: crew.

although the well integrity was not established.

2. The annulus cement failed to isolate the hydrocarbon zone and allowed hydrocarbons to flow from the formation into the wellbore.

Ó By Studying the Macondo well case study , it was found that: Ó Cementing of a well ought to be done carefully and companies ought to never move to the following stage

3. Hydrocarbons entered the wellbore undetected; the rig

unless the well respectability is set up. Once establishing

crew ignored the abrupt pressure changing readings

is done companies should run well integrity tests to ensure

from the Macondo Well monitoring system.

a successful cement activity. As BP sent Schlumberger

4. The shoe track cement could not provide a strong barrier to the hydrocarbons and allowed them to enter into the production casing.

5. Float valves were not converted, which allowed hydrocarbons to rise up in the production casing.

6. BOP system completely failed to seal the wellbore.

7. Delay in the recognition of the hydrocarbons influx. The crew could not realize the influx until it entered into the riser.

8. Well control actions after explosions failed to regain the control on the well.

9. Diversion of the flow towards MGS resulted in gas venting to the surface of the rig.

10. Lack of real leadership and unprofessionalism was another big contributor to this incident.

group home without performing cement integrity tests which turned out to be a wrong choice. Ó Cement slurry design ought to accord to the wellbore conditions and its strength and uprightness ought to be tried before sending it into the wellbore. As BP did not have any desire to sit tight for the bond slurry integrity results about rather they raced to cement the Macondo Well. Therefore they wound up with an extremely poor cement job. Ó After completion of a cement job the positive and negative pressure tests to set up the well integrity ought to be done and perused deliberately. Confusion of their outcomes can prompt a blowout as occurred at the BP Macondo well. Ó There ought to never be an absence of real leadership at the rig because drilling a well is a consider team work and a team cannot succeed without a great leader.

Onshore well was taken as an example for Egyptian blow out well was at The Western Desert.

Comparing between the two cases (Macondo of Gulf of Mixico and the well of Egypt) it was found that:

Ó During lost circulation, drilling process ought to be ceased

1. The pressure of Macondo was higher as its deep water

and lost circulation sites ought to be stopped before

horizon and the depth of the waster was extra weight and

46 Petroleum Today - October 2019

extra pressure affect on the overburden pressure which in

and the leak in pipe rams, while the Egyptian well the

turn affect on the total pore pressure of the well.

loss of circulation affect on Hydrostatic head.

2. The two killing methods was different as in Macondow they tried with Kill mud then with relief well and finally the top hat. In case of Egyptian well we tried to kill the well with kill mud and Engineering method was the best 3. Macondo was off shore while the Egyptian well

is

onshore.

5. The depth of Macondo was too high while the Egyptian well was 4600 m as TD. 6. The total cost of killing for Makondo was too high (over 20 billion dollar) while the Egyptian well was low killing cost ($ 50.000).

From all the above discussion, we can find that, well control

4. The 2 cases was completely different in the reason of bow

is a vital process as it may cost the life of the rig crew and

out: The Macondo because the cement job was not good

must be early detected to avoid disaster as Macondo well.

The main categories of oil well control

Offshore Blowout preventer.

Petroleum Today - October 2019 47

Moniring Drilling parameters for early kick detection

Drilling Simulator to simulate killing process

UNDERGROUND BLOWOUT at ONSHORE RIG

Use remote chock to control the blow out well

48 Petroleum Today - October 2019

UNDERGROUND BLOWOUT at OFFSHORE RIG

TransGlobe Energy Corporation, in an interview with Petroleum Today Magazine highlights the remarkable strides Egypt has taken to modernize its petroleum sector and the opportunities for further investment, TransGlobe ,s steering strategy towards stable production along with the company ,s aim to expand it ,s operations in Egypt through synergistic acquisitions

Can we update our readers insight on the TransGlobe strategy in light of the current oil market?

Given the ongoing oil price volatility, TransGlobe is continually focused on strict capital discipline through operational cost controls andminimizing our exposure to financial leverage by remaining debtaverse. Despite fluctuations in the markets, we position ourselves as a nimble company with the ability to create value through a balanced portfolio of exploitation, development and exploration opportunities across our diversified onshore assets in Egypt and Canada. This approach has enabled us to build our production base and generate strong cash flows, as demonstrated by recently declaring and payingour first dividend (US$0.035 in August 2018) since 2015.

AN INTERVIEW WITH

Mr. RANDALL C. NEELY, C.A., CFA President and CEO, Director TransGlobe Energy Corporation

Where are the most promising areas / concessions the company is working in?

We are most excited about our low-risk development operations in Egypt and are especially focused on the continued expansion of our Eastern Desert Concessions. As such, we are currently working alongside the Egyptian General Petroleum Company (EGPC) to extend the concessions and amend our licenses to encourage the increased development and recovery of the oil in place through secondary and tertiary applications as well as horizontal drilling and multi-stage completions. Subject to approval from the Egyptian government, the amendments sought should allow for improved efficiencies and increased reserve recovery from known oil pools through enhanced recovery techniques.

TransGlobe has been working in Egypt for more than a decade, what are some attractions in the Egyptian petroleum sector?

The production and distribution of oil is an integral part of Egypt’s economy and the country has developed a well-established service industry to support exploration and development operations, exemplified by the increasingly large and talented workforce.

This presents an exciting opportunity for TransGlobe to operate within. On the other hand, the challenges that we face include inflexible contract terms that aren’t always reflective of the underlying assets and varying interpretations of any grey areas. Nevertheless, the leaders within the Ministry and EGPC are admirably working towards modernizing the industry which should lead to a stronger and more investible operating environment.

What is the amount of TransGlobe`s 2019 allocated budget here in Egypt with reference to other countries? And how many wells do you plan to drill during the current calendar year?

Our 2019 capital program equates to $34.1 million (before capitalized G&A), which includes $24.1 million for Egypt and $10.0 million (C$13.0 million) for Canada. This plan is strategically aimed at maximizing free cash flow to direct at future value growth opportunities in Egypt and outside of Egypt. This strategy is also in line with our 2018 drilling campaign where we drilled eight development wells in Egypt – 4 in West Bakr, 2 in North West Gharib and 2 in West Gharib – compared to six development wells in Canada.

What is the operational update on the South Ghazalat exploration?

We recently announced in our 2018 yearend reserves update that a successful discovery at South Ghazalat and successful extensions at West Bakr resulted in positive additions of gross 2P reserves of 2.1 MMboe. Based on the positive test rates from South Ghazalat, we are in the process of preparing a development plan for the discovery. In addition to this, we are also integrating the well results into our existing database and mapping to evaluate further exploration / appraisal drilling opportunities in the area to accelerate potential early development options and hopefully lead to additional discoveries.

What is the growth strategy of TransGlobe worldwide and in Egypt?

We are primarily focused on development and production with a core view of generating strong cash flows and longterm value accretion. By steering the bulk of the company’s efforts towards stable production, we have been able to create a uniquely competitive position in the market.

Given our strength in looking at older, under-loved and under-developed assets, we cancapitalize our individual skillsets to improve field rejuvenation possibilities.

Further to this, we are also looking to expand our operations in Egypt or similarregions through synergistic acquisitions, and in doing so, we hope to triple our production output and more importantly cash flow in the medium term. Having said that, having a little exploration success along the way is always welcome.

Why did you exit the business in Canada then decided to re-enter the business in 2015?

Our decision to exit and later re-enter Canada came from a strategic desire to diversify our portfolio of development assets and gain exposure to the increasing technological advancements in North American drilling and completion techniques. Our Canadian re-entry was part of the Company›s ongoing strategy of portfolio diversification into countries with attractive netbacks to support growth.

This decision inevitably played to our core strength of value creation through development drilling and reservoir management.

What are your plans to mitigate oil price downturn?

We have been able to weather unpredictable markets by maintaining control over our own operations and focusing on opportunities where we can operate most efficiently. Because we are the operator of all our Egyptian assets and the majority of our Canadian assets, if oil prices shift materially we can react quickly. We’re not forced to push ahead when it isn’t favorable to do so and we can therefore control our costs accordingly. Conversely, in periods of rapid price appreciation we are able to move swiftly in order to capitalize on those opportunities to our greatest benefit.

You have a great journey with different positions and exposure, we would like to hear your story?

I was born in Eastern Canada but spent my formative years in the Yukon Territory, where I established many close friends that I still have today. Post high school I spent a few years working odd jobs, including an oil exploration supply ship in the Arctic Ocean, and traveling. That traveling brought me to Egypt for the first time in 1986, when I visited Cairo, Aswan and Luxor, an amazing experience for a 19 year old. Realizing I couldn’t travel and work odd jobs the rest of my life, I enrolled in Business at the University of Calgary, graduated in ‘92 and joined the chartered accounting firm of KPMG in Calgary.

Following that I spent about four years as an energy investment banker until one of my clients enticed me into the energy business where I have been ever since.

Finally, we would like to know about TransGlobe CSR policies and activities in Egypt?

TransGlobe have been supporting the Ras Gharib hospital for many years, as a recipient of choice as suggested by our Joint venture employees. Our production assets are close to city of Ras Gharib on the Gulf of Suez and a large number of our joint venture employees live in Ras Gharib and have a strong attachment to the hospital. In 2013, TransGlobe provided support to of fund the establishment of the first intensive care unit at the hospital and we continue to support the unit with donations to fund the acquisition of specialist heart and lifesaving equipment on a regular basis. TransGlobe makes the donations to the hospital whenever a significant HSE achievement is reached so that we are improving safety continually as well as supporting an essential local facility in Ras Gharib.

In addition to this, TransGlobe has 2 staff members on the CSR committee, which is a subcommittee of the Egypt oil and Gas technical committee. Although only recently formed, this committee is already very active in liaising with other IOC’s to share and align CSR activities across the industry.

Petroleum Today - October 2019 51

Technology Applications Electrical Submsersible Pump Powered Injection ESPPI Systems Enable the Development of West of the Nile Egypt Assets By: Miguel Munoz and Mohamed Aboutaleb, Qarun Petroleum Company; Jeff Dwiggins, Artificial Lift Solutions Pte Ltd

A

bstract

Qarun Petroleum Company (QPC), a joint venture between the Egyptian General Petroleum Corporation (EGPC) and Apache Egypt, operates over 350 ESP wells in brownfields across the Egyptian Western Desert.

QPC,s oil production is heavily dependent on the performance of waterfloods and artificial lift systems. In recent years, QPC entered a development campaign in the West of Nile (WON) region, an area located west of the Nile River approximately 159 kilometers from Cairo. The fertile land has ready access to irrigation and therefore long been developed as an agricultural area, surrounded by densely populated villages.

Land access is restricted and operations must be conducted to ensure minimal impact to the environment.

Oilfield development in WON is challenging and required alternative solutions to conventional waterflood operations.

QPC engineers turned to ESP Powered Injection (ESPPI) systems as an alternative to traditional waterflooding and re-engineered the technology to overcome the operational, economic, and environmental challenges.

ESP Powered Injection (ESPPI) systems utilize conventional ESPs in combination with a bypass system (Y-tool) and an injection string to provide water production and injection support from a single wellbore to one or more wells in the same injection pattern. The system eliminates the need for surface pumping, water separation, storage, and flow lines.

QPC has successfully installed and presently operates nine

52 Petroleum Today - October 2019

(9) ESPPI systems in the environmentally sensitive WON region of Egypt.

This paper aims to detail the specifications and functionality of ESPPI systems, main challenges and benefits derived from closed monitored installations and operational surveillance, and the economic advantage of its application for QPC.

Introduction

QPC operates the country›s second largest ESP portfolio in the Egyptian Western Desert. The company has over 350 ESP systems running at any given time across nine (9) concessions. QPC is also considered the largest waterflood company in Egypt with 85% of its fields under waterflooding with improved recoveries ranging from 10% to 35%. Fig. 1 shows QPC,s three (3) main areas of operations and waterflooding (Karama, Qarun, and Beni Suef where the WON concession is located).

The WON concession, situated approximately 159 kilometers from Cairo, Egypt,s Capital, as illustrated in Fig. 2, formed an important part of QPC,s undeveloped assets. In 2011, QPC initiated a development drilling campaign in the WON after drilling the WON-C01X exploration well and proving commercially.

Development plans of WON wells required waterflooding as early as possible in the life of wells to sustain production rates and commercial recoveries. The producing reservoirs were proven to be depletion drive reservoirs primarily.

Initial attempts at conventional waterflooding operations proved unsuitable for the development of WON wells.

Agricultural area overlays, limited opened land, and restricted accessed roads presented operational constraints ruling out minimum equipment requirements and operability of surface water injection networks.

Dense populated villages and agricultural activities in the area presented high environmental and safety concerns.

Natural dump floods, operated by the company on various other fields, came short of meeting water injection pressures and desired target rates. WON reservoirs range from 15 feet to 25 feet on thickness at the injection zone, typically at a depth of 6,600 feet TVD, demanding high injection pressures and costly surface pumping systems to reach desired injection rates.

The ESP Powered Injection (ESPPI) System

ESP Powered Injection technology involves producing and injecting water in the same wellbore through an ESP and a modified by-pass system (Y-Tool) shown on Fig. 3. An ESPPI system is essentially a single wellbore water-source water-injection system. The system uses an ESP and Y-Tool to produce water from a water zone and direct injection to a desired injection zone. In current QPC applications, the ESPPI system produces water from a shallower water-source zone at approximately 6,000 feet and injects the water into a deeper injection zone typically at 6,600 feet.

The ESPPI system is a versatile application with configurations easily modified by simple wireline operations.

The system can be used as a water-source well for nearby waterfloods serving surface-waterinjection manifolds while fully functioning as a complete water-source water-injection system within the same wellbore. The system can operate in three (3) basic positions or functionalities as described below in Fig. 4.

One of the main advantages of the ESPPI system is the elimination of waterflood surface facilities when operated on position B. When the system operates on the B position, the waterflood operation requires no separate water injection well, installation or laying of flow lines, water storage tanks, skimming tanks, or surface pumping systems. The exclusion of the mentioned surface equipment and facilities reduces the footprint of the waterflood operation to a single wellbore and surface Christmas Tree. In addition, field development economics are also greatly reduced from the elimination of a separate water-injection well.

In short, the system is considered very «environmentally» friendly while achieving the necessary downhole conditions to allow effective production. Fig. 5 shows a typical WON ESPPI well with no waterflooding surface facilities or flowlines.

QPC ESPPI System

QPC ESP engineering team performed a research of Powered-Waterflood-Injection systems installed and operated worldwide. The study showed that main challenges on system designing were related to low permeability injection zones of less than 10 md, and limited reservoir thickness of the injection zone.

Mechanical and operational challenges included jetting effects on down-hole tubulars from high-pressure water source zones and cable damages, long back spinning periods of the pump from charged reservoirs, and extended rig time consumed on equipment make-up and installations. The team worked diligently to address many of these challenges and executed the following modifications: Ó Performed ESP designs taking into consideration the producing-water-source zone and waterinjection zone Ó Selection of mixed-flow wide-range pumps with wider operating ranges to accommodate reservoir behavior changes and demands of future water injection rate adjustments Ó Installation of a locked blanking plug in Y-block rated to 5,000 psi differential pressure to close the Y-tool system loop Ó Setting of the ESP system in 9 5 / 8″ casing to avoid limited clearance of 7″ liners Ó Inclusion in the tail assembly of the following: - VAM TOP Blast joints set against water-source zone and perforations - Self-aligning tool to sting in tail assembly in permanent packer - NU Seal units - Permanent packer to isolate water-source zone from injection zone with UN seal bore extension Ó Use of FJL (Flush Joint Liner) tubing with premium flushed connection threads in bypass tubing for edge-toedge sealing and for higher clearance with the ESP Ó ESP pump selection of 538 series pump, and motors of 562 series Ó Bypass tubing BHA to be pre-assembled prior to arriving at wellsite. Then, make use of torque wrench on rig site for BHAs assembling to save rig time Ó Real-time surveillance Scada system to be installed on every well for 24 /7 monitoring Ó Limiting the tail assembly weight to 28,000 lbs.

System Developments and Lessons Learned

ESPPI systems became the standard waterflooding method

Petroleum Today - October 2019 53

in QPC WON fields since the installation of the first system in December 2015. The first ESPPI system installed proved successful in the WON C-315 well with an injection rate of 1,200 BWPD. Reservoir pressure was restored to virgin pressure of 2,900 psi in a period of approximately 16 months. Since then, QPC engineers worked on a number of improvements of the technology as field development plans advanced. The ESPPI system installed in the WON C-315 well failed after 177 days with a reported motorshort circuit. A Dismantle Inspection Failure Analysis (DIFA) performed on the system discovered well fluid entry at the motor head with the motor oil smelling burned. During the ESP operating run life, the motor oil temperature measured 245°F while the recommended operating temperature range of the motor was 165°F 250°F. The motor operated nearest to the upper temperature ranting. The source of well fluid entry was a concern but undetermined. The main corrective action from the subject installation included the use of a higher rating motor oil with an operating temperature range of 210°F - 300°F to avoid similar premature failures.

QPC,s second ESPPI installation in February 2016 ran for 649 days. A performance improvement of 472 days of run time. The system was pulled and another one ran in the well with a larger size ESP. The objective of upgrading the size of the ESP was to have the ESPPI system serve as a watersource well to a nearby injector unable to meet its injection target while fully functioning as an ESPPI system in its original wellbore.

Subsequent ESPPI installations, including installations in the conversion of three (3) underperforming oil producer wells to water injection wells, have performed to expectations with minor challenges. QPC production engineers experienced problems with the system blanking plug becoming stuck in the nipple above the Y-tool. The situation prevented Production Logging Tools (PLT) operations in the wellbore and the measurement of injection flow rates.

To address the problem temporarily, water injection rates and ESP surveillance was conducted via downhole sensor readings and analysis of offset oil producing wells in the same waterflood pattern. As a permanent solution, QPC production and ESP engineers replaced the blanking plug with a Back Pressure Valve (BPV) installed at surface in the Christmas Tree.

QPC has completed the installation of nine (9) ESPPI systems in the WON area. Total injection rates add up to 13,300 BWPD per day and approximately 5.2 MM barrels of water injected comulative as of February 2019. Oil production as a result of water injection is estimated at over 4,500 BOPD. Fig. 7 illustrates ESPPI systems installed and under operation by QPC in the WON fields.

54 Petroleum Today - October 2019

Cost Saving Impacts

ESPPI systems have offered QPC important cost savings, both capital and operational, that aid the development of WON fields. All of this has been achieved while being sensitive to environmental conditions. As previously mentioned, ESPPI systems eliminated the need of a separate water-source well and injection wells typically required on conventional waterfloods. Surface facilities are not required including installation and laying of flow lines, tanks, or surface-injection pumps. Main capital costs savings include the following: Ó Drilling and completion of separate water-injection wells and water-source well Ó Purchasing or flowline materials and fittings Ó Purchasing and installations of tanks Ó Purchasing and installations of surface water injection systems The operational cost savings from ESPPI systems are significantly dependent of the application of the system and the company operating philosophy. QPC realized significant operational cost savings in the range of $180,000 - $200,000 per year from an ESPPI system operated on position C (Fig. 4). In future applications, operating cost savings could include, but not be limited to, land rental, other equipment rentals, surveillance system charges, personnel supervision chargers, and power related costs.

Way forward

QPC plans to extend the application of ESPPI systems to other areas of operations and take advantage of the developed in-house experience and field staff familiarity with operating the technology. QPC ESP engineering team plans to work on further modifications of the system to address the challenge of backspinning of the pump. The team plans to try a Variable Speed Drive (VSD) technology featuring a catch spin while running mode. In addition, QPC ESP engineering plans to test other less conventional tools such as TubingDrain Valves (TDV), Auto-Diverter Valves «ADV», and Non-Return Valves «NRV to relief back pressure on the pump after restarting back the system.

Conclusion

As of February 2019, QPC operates nine (9) ESPPI systems averaging 13,300 BWPD of total injection.

Production gains as result of the unconventional waterflood operations are estimated at over 4,500 BOPD total for the nine (9) ESPPI systems. By eliminating the requirement of separate wells for water production and injection,

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development costs and footprint are greatly reduced.

Elimination of surface water handling facilities further reduced costs and environmental impact. The closed loop nature of the ESPPI system also has the advantage of eliminating the hazard of high-pressure surface injection

lines, pollution by organic agents, or contamination by surface facilities corrosion. As a result, ESPPI systems made possible the economic development of QPC environmentally sensitive WON fields.

Figure 1—QPC main areas of production and waterflooding operations

Figure 2—Egyptian Wester Desert, QPC Central Processing facilities, and West of Nile operations

Figure 3—ESP Powered Injection System and Y-tool assembly

56 Petroleum Today - October 2019

Figure 4—ESP Powered Injection System configurations

Figure 5—ESPPI system well WON C 315 of QPC with no surface facilities

Figure 6—QPC ESPPI Assembly

Petroleum Today - October 2019 57

Figure 7—ESPPI systems installed and running in QPC. Water injection rate increases and production profile from waterflood operations

Table 1—CAPEX cost savings comparison between a conventional waterflood and an ESPPI waterflood

58 Petroleum Today - October 2019

Technology Applications Integrating Big Data:

Simulation, Predictive Analytics, Real Time Monitoring, and Data Warehousing in a Single Cloud Application By: N. Mounir, Y. Guo, Y. Panchal, I. M. Mohamed, A. Abou-Sayed, and O. Abou-Sayed, Advantek Waste Management Services

A

bstract

The E&P industry is rich in all types of data.

Without proper database and analytics, companies are not able to retrieve and analyze the data they need in an efficient way. The result of the data management problems is that decisions are often made using incomplete or incorrect information. Even when the desired data is accessible, requirements for gathering and formatting it may limit the amount of analysis performed before a timely decision must be made.

Strong data management is required to transform wellsrelated data into an integrated system of information.

The key to successful data management is in the use of sophisticated platform-independent codes that doesn›t need any special setup or systems which allows easy transfer of information and data over the internet. This paper describes the data management and accompanying analytics approach taken in support of operations in Egypt to provide a shared knowledge system.

This innovative cloud application provides a common interface to multiple systems in the organization, allowing a richer and more complete source of data to be used for decision making. Moreover, it enables the integration of static data, such as well logs in a particular region, with a real-time system to facilitate integrative real-time analyses using artificial intelligence, cloud-hosted physics-based simulators, or both.

To support deepwater needs such as those in Egypt, the system incorporates productivity optimization analysis, reservoir geomechanics (pore pressure prediction, log interpretation, reservoir collapse, fault activation, subsidence, compaction,

62 Petroleum Today - October 2019

etc.), and data mining of key development uncertainty and well performance drivers.

Introduction

The oil and gas industry is rich in many different types of data that needs to be stored, retrieved and analyzed efficiently to manage operations. Because of the complexity of operation problems to be addressed, more than one piece of software is often required to complete a specific data analysis process. The lack of integration and the poor compatibility of required software and data has been a challenge for effective data management and analysis at every phase of field development cycles.

The integration between different software solutions can be quite tricky even though each software may have clearly defined input and output parameters. If the integration is not done automatically, manual modifications of input and output parameters after each calculation iteration make the integration subject to human error and inefficiencies.

Inconsistent data formats and incorrect understanding of data requirements can also hinder a smooth data transition.

Data links or data conversion systems may be developed to facilitate the data transition; however, these may not be applicable to the same software if the software is updated andits data format is changed. Thus, the data conversion systems may have to be modified to accommodate the change in any of the integrated software even if the change is small.

These modifications however can be time and resource consuming. As the success of field operations may heavily rely on the analysis of daily operation data at well level or field level, the inability to convert/link the data in a timeefficient manner can compromise the workflow severely,

leading to reduced operation efficiency and even failure.

application can be found elsewhere (Guo et al., 2017).

The data storage concept has been strongly promoted as a solution to all data integration issues. In order to improve data accessibility, warehouse/storage generally exist as relational databases, multidimensional OLAP (online analytical processing) databases, or data cubes. Although the standardized data storage has greatly simplified data integration processes, the data integration can still be problematic because of imperfect data as summarized below:

Unlike traditional desktop applications, the web based application is installed on a web server and is rendered by a web browser (Figure 1). It therefore does not need to be installed by users before use. Users can launch it from any web-enabled device with a web browser. Data required for any analysis can be loaded either from local discs or from the shared database. The analysis results are saved in the shared database but can be downloaded to the web-enable devices. In this way, any data and analysis results identified by either a unique project name or a well name can be shared easily and simultaneously through a web browser.

Ó Data compatibility: data unit, format and other properties defined differently in each database. Ó Data completeness: incomplete dataset without all the requisite information; missing and/or unusable data. Ó Data consistency: distinct occurrences of the same data instances providing conflicting information, such as inconsistent data values.

Permission however is required to access any protected data and analysis results.

Cloud) so that data transition and analysis can be done by any web-enable devices at any locations with

Ó Data validity: incorrect or unreasonable data.

internet access in the world.

Ó Data conformity: data in an unexpected format.

The data analysis tools built in the web application automate field planning and surveillance by enabling the following activities: 1) Data mining and view capabilities to enable engineering field studies for decision support; 2) Automated log blocking and geomechanics analysis; 3) Interactive and automated pressure transient analysis; 4) Hydraulic fracture design & stimulation performance analysis. In particular, log analysis tools that include all published log analysis models allow stresses, pore pressure and rock mechanical properties to be derived using optimal algorithms. The optimal algorithms are identified based on the availability of logs and well location. Thus, users without any log analysis experience are able to perform the analysis and produce expert level results. Users can also manually select log analysis models in case outputs are not consistent with calibration data and different models need to be applied.

The logs and log analysis outputs are automatically blocked according to predefined formation tops or formation thickness. The blocked data is ready to be used for other analyses, such as reservoir simulation and hydraulic fracture simulation.

Ó Data integrity: data correlation affected by missing data.

Besides software and data integration, data communication between data acquisition/storage systems and data analysis tools is also critical for efficient data analysis, particularly for data analysis in real-time. There are barriers that prevent users from finding and using the data they need, such as: Ó Data acquisition/storage systems are not updated in a timely manner. Ó Reporting and exporting user interfaces of data acquisition/ storage systems are too complex to retrieve and import data. Ó Analysis tools do not take into account new data and extract useful information from the latest data to meet evolving business needs. Ó Data from data acquisition/storage systems cannot be modified easily to meet the data requirements of analysis tools.

Methods

By recognizing the inefficiencies and difficulties of manually integrating data and software for complex analyses in oil/ gas industry, a web-based integrated application solution has been developed using ASP.NET to enable subsurface engineers to perform a broad range of analyses related to exploration, production and disposal processes. It provides stimulation, production and injection engineers a common set of tools that they need to perform their typical workflows.

It also offers an integrated database shared by all built-in tools and users. Moreover, it includes workflow creation tools to enable assembly of workflows from preexisting elements (data types, simulators, etc) to be created within the application. This paper will focus on the key features of the cloud application, while a detailed description about the

Some of the analysis tools are sophisticated numerical simulators, such as built-in powerful 2- Dimensional and 3-Dimensional fracture simulators that are equivalent to fracture simulators @FRAC2D (Elkatatny, et al., 2014) and @FRAC3D (Zaki, et al., 2004; El-Fayoumi et al., 2011).

The analyses based on such tools demands a significant amount of computing power. The analysis may not be carried out time efficiently even with a fast laptop. More powerful devices with on-demand computing resources, such as cloud virtual machines, are ideal to get simulation results in a timely manner. The web application is therefore cloud based and developed upon a distributed computational

Petroleum Today - October 2019 63

infrastructure. It can launch each additional cloud virtual machine for any data analysis and simulation request as needed. The web application is therefore capable of running a massive number of parallel simulations simultaneously.

Thus, time consuming numerical simulations can be done quickly with any web-enabled devices through the web application, such as a smart phone. This ability also enables novel solution approaches which are not practical in single machine instances.

To take full advantage of web-based cloud computing, realtime monitoring capability has been also developed in the web application. Real-time operation data can be pulled from field sites and pushed into the Microsoft Azure cloud database by the web application. The web application not only provides a way to automatically load and display both stored and real-time data from Azure cloud database, it also offers a tool for automated monitoring. Users can define threshold values and critical variation trends for any realtime data. If the real-time data exceeds predefined threshold values and/or varies in unexpected trends, an alert email and/or a text message will be sent to users immediately.

The automated monitoring may significantly reduce field operation cost as a dedicated team is not required anymore for real-time monitoring on a 24 / 7 basis.

To enhance the capability for real-time fracture analysis, a tool for pressure falloff analysis that incorporates most published standard methods along with several proprietary methods is included. The tool allows fracture half-length and width to be estimated from pressure falloff analysis after any injection event, and then to be compared with the geometry predicted by the 3D fracture simulator, providing further assurance of fracture containment / geometry. Compared to log based analysis, the pressure falloff analysis yields more reliable estimations of injection / completion zone minimum stress and pore pressure, and their variations over time as a result of cyclic injection. Thus, the input parameters for the 3D fracture simulations can be tuned based on the results of pressure falloff analysis after each previous injection event, which leads to a more reliable fracture prediction and a better understanding of injection effects on fracture geometry and spatial distribution. A more advanced pressure falloff analysis tool is also available in the web application.

The tool is equivalent to previously developed desktop application @IPT for fracture geometry assessment (Loloi et al., 2014), and capable of analyzing pressure falloff data for long term fracturing injection operations.

Case Study

Egypt is rich in oil/gas. Many oil/gas fields have been discovered and developed since 1900 (Figure 2). The consumption of oil/gas in Egypt has increased rapidly while

64 Petroleum Today - October 2019

it›s production has been declining since 2010 as shown on the website of tradingeconomics.com. In order to develop existing and new fields in a costeffective way and encourage more exploration activities to boost production, it is critical to reduce field operation cost by optimizing drilling, completion and production programs, which requires an efficient way to analyze existing field measurements such as, for instance, wireline logs to gain a better and thorough understanding of reservoir properties and field operation conditions.

In order to demonstrate the effectiveness of the web based application to improve the efficiency and reliability of data analysis and help reduce operation cost, the workflow and the results of a geomechanics study is presented in this paper to show how the web based application can facilitate and automate field data management and analysis in environments such as those in Egypt. For data analysis, the focus was on formation stress estimation, rock property evaluation and fracture simulation although many other analyses can also be conducted using web application.

The wireline logs required to carry out the presented study were collected from a well in one of Egypt oil fields, including Gamma Ray (GR) and density measurements (Figure 3). The logs, originally saved in the industry standard format (.las), are loaded automatically to the remote shared database through the web application user interface.

The automatic data loading modules of the application also supports other common data format, such as .csv and .txt. Once the logs are loaded, any users with appropriate permission can retrieve, view and analyze the data through the web based application from any web-enabled devices at any time. Since data collection is often the most timeconsuming step for any field data based analysis, if all well logs and field measurements are saved in the shared database, the efficiency of the analysis is improved. In addition, users do not need to spend time to modify data format and/or unit because they do not have to load data to other software for analysis.

Data analysis, particularly, log analysis to estimate the rock properties and stress state of the study area, is fully automated. All algorithms and equations for log analysis published in the past have been built in the application.

These algorithms and equations are optimized in such a way that the most appropriate algorithms and/or equations will be selected to perform calculation dependent on the types of input logs and the locations of study areas. Thus, log analysis performed by inexperienced engineers yields the same results as those done by seasoned experts. Besides automated analysis workflows, the application also allows users to define their own workflows in case manually defined workflows are expected to yield better results. The

Since 2003, flow measurement Systems Company has been established according to the investment authority laws and executive regulations to serve the oil &gas sectors as well as industrial & commercial sector in Egypt & the region to provide hydro test and calibration services.

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PRESSURE TEST (Hydrostatic & Pneumatic) Ó Fully computerized and plc controlled test unit, capable of building pressure up to 30,000 psi by using two air-driven pumps, one for quickfilling and the other to build up pressure to the test value. Ó The pressure test Monitored digitally on system wide screen and recorded on paper charts to issue full test report. Ó Camera system is installed for monitoring the test and observing any leakage. Ó The test unit operated with remote control systems in a safe Test Area.

PRESSURE SAFETY VALVE CALIBRATION AND TESTING We undertakes Inspection, Overhaul, Calibration and Certification of all types of Pressure Relief Valves AS (A SAFETY RELIEF VALVES , PRESSURE SWITCH And PILOT VALVES ) with high accuracy equipments( Ventill test unit , Haskel gas boosters , pressure sensors ) FMS carries out these jobs according to procedures developed ‘In House’ conforming to the requirements of BS EN ISO4126 : 2013, API-527, API-598 and API 576 standards.

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algorithms and equations for each module can therefore can be selected and connected to create a specific workflow.

Their input parameters can be also defined in a preferred way.

For this specific analysis, it takes almost no time to get the results as the automated workflow was applied. In addition, the analysis is done on remote cloud virtual machines with on-demand computing resources. The speed of analysis is therefore not affected by the computational power of user,s devices that are used to lunch the web application. The analysis results can be shared instantly with other users as soon as the analysis is completed.

Rock mechanical properties derived from logs include all elastic moduli and rock strengths, as well as petrophysical properties, such as permeability, porosity and clay content that are necessary to conduct all types of geomechanical analyses (Figure 4). For demonstration purpose, Figure 4b only shows the rock mechanical properties that were used for fracture simulation, including Young,s modulus, Poisson,s ratio, fracture toughness and leak off coefficient. Although these properties were derived only from GR and density log, they are consistent with general field experiences and observations.

Besides rock mechanical and petrophysical properties, stresses and pore pressure are also important outcomes of the log analysis module (Figure 5). Vertical stress is calculated from the integration of available density logs and/or pseudo density logs derived from other logs, while horizontal stresses are defined as a function of pore pressure.

Horizontal stresses may be calibrated against measured stresses and those estimated from wellbore failures. Several pore pressure prediction algorithms are built in the log analysis module. They provide flexible ways for users to adjust their pore pressure predictions based on pore pressure measurements and field experience. In addition, the web application allows multiple stress models to be built based upon the same suite of logs, but different combinations of the algorithms. Thus, the applicability of each algorithm can be evaluated easily, and the most likely stress model can be identified confidently based on the direct comparison of the stress profiles. The most likely stress model for this study was created also based on the field experience in the study area.

The log analysis results usually serve as inputs for many types of studies, such as reservoir simulations and simulations of hydraulically induced fractures. These studies require rock properties and stresses derived from logs to be layered or meshed according to actual formation tops because of the variations of formation depth and thickness across study areas. The ÂŤlayeringÂť process is done automatically if formation tops are predefined (Figure 6).

The web application also offers other ways to divide the

66 Petroleum Today - October 2019

logs and log derived properties into layers. For example, they can be layered automatically according to user defined layer thickness. Each layer can also be adjusted manually if there is a need. The layered properties are automatically loaded to any simulators built in the web application.

More complicated automated meshes are available and if a reservoir-scale model is built upon logs from many wells in a structurally complex field, the automatics meshing or layering (and kriging) functions can greatly reduce the amount of time required to build such model.

The layering for the fracture simulation presented was done based on lithology variation identified from GR log as shown in Figure 3. Besides the geomechanical properties, the same layering criteria were also applied to all other data/properties required for a successful fracture simulation. The layered geomechanical properties for the fracture simulation are shown in Table 1. The highlighted layer is targeted injection interval. The interval was selected for injection mainly because high minimum stress layer above the interval may serve as a good stress barrier to ensure fracture containment (Figure 5).

To confirm the effectiveness of the stress barrier, injection induced facture geometry needs to be evaluated under real injection conditions. The 3-D fracture simulator built in the web application was used to model the growth of fracture and examine its containment. The fracture simulator has the capability to predict fracture propagation through layered formations. Both injection rate and fluid properties such as fluid viscosity and solid concentration can vary during the simulation, which is convenient for optimizing injection parameters in complex injection operations. At the injection design stage, the simulation provides an estimate of fracture width, length, height and volume as well as net pressure distribution which are critical parameters to optimize the injection operational parameters and calculate the formation capacity.

For the fracture simulation presented here, fluid with 10 Vol.% solid loading was injected into an interval between 6172 ft and 6492 ft at a rate of 10 bpm for 24 hours. The evolution of the predicted fracture is shown in Figure 7. The temporal variations of the fracture geometry and internal pressure distribution can be plotted in separation plots or in the same plot for comparison. The plot of spatial variation of fracture geometry is also available at any given time.

The fracture profile at the end of the injection is plotted with stress profile in Figure 8 to illustrate that the fracture is contained within the injection zone. As fracture width is not constant and the distribution of solid and pressure inside of hydraulic fractures are usually not uniform, a contour plot can be generated to help visualize the variations of these properties. As an example, Figure 9 shows a contour plot

of fracture width, suggesting that fracture width decreases gradually from wellbore to fracture tip. The outputs of the fracture simulation are not only useful for injection designing purpose, they are also helpful for the interpretation of puzzling injection data (Guo et al., 2017).

Discussion

As demonstrated by the case study presented from Egypt, the web application provides an ideal platform to store, access, retrieve and share data. The platform is particularly useful in the Egypt context as there is no similar cloudbased database or equivalent platform available for the oil/gas industry. Moreover, in a country whose oil and gas industry has traditionally been reliant on expatriated engineers to provide senior level technical leadership, the web application›s expert workflows allow a broader set of professionals within Egypt to provide high quality analyses.

Because of poor data management systems for data collection and communication in Egypt, data analysis has traditionally been much less efficient than in other countries.

To fundamentally improve the data analysis efficiency, better data management platforms or databases, such as the web application presented here, must be employed to enhance data management efficiency in terms of data access, query and visualization.

As a good example, a cloud-based SQL database has been constructed through the web application for Gulf of Mexico (GoM). The database was built upon data collected from a significant number of GoM deepwater reservoir/wells, including full-life deliverability, integrity, completion options and reliability linked to reservoir characteristics and well and completions attributes. Thus, it allows operators to access data that may take months to collect and clean up.

In addition, built-in knowledge management tools can help operators address both reservoir and well characteristics that affect the best practices in depletion strategy, completion, and sand control versus reservoir architecture and drive mechanisms with extension to Paleogene deposits in ultradeep-water regions within the GoM (Amirlatifi et al., 2018).

When viewed in the context of specific decision support models based on actual field performance data, the database provides highly valuable time and cost savings and economic incentives for deep water operations. If a similar cloud-based database were built or expanded to include all offshore or deepwater exploration, drilling, completion and full field life production data, it could dramatically reduce the time and costs for offshore developments worldwide. In addition, because the database is cloud based and users with appropriate permission can download and upload data and perform analysis through the web application, the database does not just serve as a data source but more importantly, it

can act as a dynamic data and knowledge library. Users not only just get data and knowledge from it and they can also add their data and analysis results to the database and shared with others.

Besides data management efficiency, data analysis efficiency is also affected by the efficiency of data communication among analysis tools. This is particularly true for complex analysis, such as fracture simulation as shown in the paper. In the past, multiple applications were required to conduct the simplest fracture simulation, such as a geomechanics software to build earth geomechanical model while a separate fracture simulator was essential for fracture propagation predication. These applications, however, are usually not compatible with each other as they were developed to achieve different objectives. Significant amount of time had to be spent to modify the formats and units of output parameters from one software in order to load them to another application. The inconvenience not only increased analysis time and cost, but also frequently led to wrong results because of mistakes made during the data transfer between applications.

The web based application completely avoids such inconvenience as all built-in analysis tools are sharing the data with consistent units and formats in the same database.

Thus, fracture analysis can be done more time-efficiently as users do not need to deal with the data format and unit issues, and import and export data manually. In addition, the automated and standardized workflow allows the analysis to be done by non-professionals in the same way as professionals. The reliability of the analysis results is therefore not dependent on the knowledge level of users.

The setup of standard workflows however does not limit the applications of user›s knowledge and experience to optimize the predefined workflows. In fact, the application allows users to choose appropriate models and modify their input parameters wherever possible although the ultimate goal of the application is to continually optimize the workflows based on up-to-date field measurements and observations in the database through data mining rather than based on individual experience.

In the oil/gas industry, field measurements often need to be processed and analyzed remotely in real time to minimize risks of field operations, such as drilling and injection.

Previously, this real-time analysis could only be done at remote data centers whose costs limited their use to only the largest service providers and operators. These data centers are costly and mainly used to support expensive deepwater operations (BSEE, 2016). Because of high cost, remote realtime monitoring of field operations is rare in Egypt although operation risk could be reduced if field measurements could be examined by experts at remote locations.

Petroleum Today - October 2019 67

The web application has not been applied to monitor any field operations in Egypt, but it has been used by engineers at Cairo to remotely monitor injection operations in worldwide.

Compared to traditional remote data center, the cloudbased web application provides a much more costeffective way to conduct remote real-time monitoring. As real-time data collected at field sites are pushed to public clouds instead of dedicated data servers at remote data centers, cost to maintain the data centers are greatly reduced. In addition, real-time data is viewed and analyzed through a web browser so that realtime monitoring can be done at any locations as long as a webenable device is available. As a result, more and more small companies are trying to take the advantage of web based cloud computing technologies and develop web applications to remotely view and analyze field data. It allows real-time data from remote field sites to be pushed to commercial clouds through wireless network and viewed from any web-enabled devices. It also provides an automatic way to monitor field measurements (Guo et al., 2017). An alert email and/or text message will be sent to users if any measurement or its variation exceeds userdefined threshold values. As automated remote real-time monitoring is essential for field site automation that can help significantly reduce field operation cost, the web application or other tools with automated monitoring capabilities will play more important roles in highly efficient and automated field operations in the future.

Although the web application has greatly simplified data management and analysis process by linking to a publicly accessible cloud database with integrated standardized workflows and automated analysis tools, it does not provide a perfect tool to automatically retrieve and load data from existing databases or public websites. In many cases, data has to be loaded manually because of the complexity of data structure that is not compatible with default data pattern assumed by the data loading tool. Practically, it is almost impossible to make the data loading tool to recognize all possible data structures as many existing databases were built upon different data standards that could be arbitrarily defined, leading to unexpected difficulties to communicate data among databases. As a result, the industry will likely continue to develop smarter and smarter data loading tools (likely relying on artificial intelligence), and or standardize data warehouse formats.

Conclusions

We demonstrated in this work how log analysis and fracture simulation for a well in Egypt using web-based application may provide an integrated solution for data management and analysis. The web application offers a more convenient way to manage data compared to desktop software, as data

68 Petroleum Today - October 2019

can be loaded to the shared database from any web-enable devices at any locations. Users can access any data through a web browser once it is loaded to the database. The analysis results can be also saved in the database for quick reference and data mining. The database therefore becomes not just a data source, but also serve as a dynamic data and knowledge library. As an integrated solution, the data analysis takes place with the automated and standardized workflows to ensure efficiency and reliability. Additionally, users can also define their own workflows if necessary. The speed and number of analyses are not limited by user-owned devices to launch the application as the analyses are conducted on remote cloud virtual machines with on-demand computing resources.

In addition, the automated remote real-time monitoring capability makes live monitoring not only feasible for expensive offshore operations, but also costeffective for onshore operations.

Acknowledgment

The authors would like to thank Advantek Waste Management Services LLC for permission to publish this paper.

REFERENCES A. Amirlatifi, G. M. Narahara, O. A. Abou-Sayed, G. Kusinski, G. Block, J. Mills, A. S. Abou-Sayed, A. Zidane (2018). Bethinking Appraisal: Identification of Pre- and Post-Sanction Uncertainty Drivers in Deep and Ultradeep Gulf of Mexico Fields Through Data Mining Will be presented at the Offshore Technology Conference held in Houston, Texas, USA, 30 April–3 May 2018.

A. Amirlatifi, G. M. Narahara, O. A. Abou-Sayed, A. Zidane, G. Kusinski, (2018). Well Performance in New Frontiers: Realizing Oilfield Big Data through Large Scal Data Analytics. Will be presented at the Offshore Technology Conference held in Houston, Texas, USA, 30 April–3 May 2018.

BSEE. 2016. Application of Remote Real-Time Monitoring to Offshore Oil and Gas Operations. https://www.bsee.gov/sites/bsee.gov/files/ technology-assessment-program-tap/ab.pdf.

Faig, C. H., Yau, W. G., Christensen and T. Elser 2002. Bridging the data, a software solution which eliminates the barriers to data accessibility providing data integration, analysis, and reporting not possible before.

PETSOC-2002 - 138 El-Fayoumi, A. M., Zaki, K. S., & Abou-Sayed, A. S. (2011, January 1). 3D Hydraulic Fracture Simulation for Injection in Plastic Shales. Society of Petroleum Engineers. doi:10.2118/ 142263-MS. Elkatatny, S. M., Farid, A., Mohamed, I., Abou-Sayed, O. A., & Block, G. I. (2014, August 18). An Advanced, Integrated Simulator for Management of Produced Water Re-Injection in Multilayer Vertical or Horizontal Wells. American Rock Mechanics Association Guo, Y., Mohamed, I. M., Abou-Sayed, O., & Abou-Sayed, A. (2017).

Injection and Remote Real-Time Monitoring: Slurry Injection Case Study, Onshore USA. SPE-187234-MS presented at the 2017 SPE Annual Technical Conference and Exhibition held in San Antonio, Texas, 911- October 2017.

Loloi, M., Abou-Sayed, A., Abou-Sayed, O., & Bill, M. (2014, August 18).

A Novel Technique for Assessment of Fracture Geometry and Injection Domain From Falloff Tests After Fractured Injection of Slurry: Case Study. American Rock Mechanics Association.

Pandey, R. K., Data Quality in Data warehouse: problems and solution. e-ISSN: 2278 - 0661, p- ISSN: 2278 - 8727 Volume 16, Issue 1, Ver. IV (Jan. 2014), PP 1824- Journal of Computer Engineering (IOSR-JCE) Zaki, K. S., Wang, G., Meng, F., & Abou-Sayed, A. S. (2004, January 1). A 3-D Plastic Fracture Simulation To Assess Fracture Volumes In Compacting Reservoir. American Rock Mechanics Association.

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CTS Egypt Scope of work Cover the below activities.

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Figure 1—Web application architecture. Data can be loaded to the cloud database through a web browser or automatically loaded from third party databases and field sites using built-in data loading tools. Data analysis is done on cloud virtual machines with ondemanded computing resources. Warning messages will be sent to users if any abnormal measurements are received during automated real-time monitoring of field operations.

Figure 2—Egypt main oil/gas fields.

70 Petroleum Today - October 2019

Figure 3—Logs collected for geomechanics analysis.

Figure 4—Rock mechanical and physical properties derived from the logs

Figure 5—Stresses and pore pressure derived from the logs

Petroleum Today - October 2019 71

Figure 6—Blocking based on Gamma Ray log.

Figure 7—Fracture geometry and net pressure predicted by the web-based simulator.

72 Petroleum Today - October 2019

Figure 8—Predicted injection induced fracture is contained within the Injection Zone.

Figure 9—Contour plot showing the solid concentration within half fracture.

Table 1—Blocked properties for Fracture Simulation,s input.

Petroleum Today - October 2019 73

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Technology Applications

Environmental Mainstreaming for Self-Regulation EMSR By: Marco Buzzo and Marco Mazzoni, Backer Hughes, a GE Company

A

bstract

This paper provides an overview of PETRONAS experience in implementing Environmental Mainstreaming for SelfRegulation (EMSR) since 2016. The commitment to mainstream environment is amplified through self-regulation approach with focus on key environmental management areas such as air emissions, water and hazardous waste management. As per the Department of Environment (DOE) Environmental Mainstreaming Directive, seven (7) EMSR critical elements were applied and mapped against existing PETRONAS HSE Management System (HSE MS) with intent to facilitate implementation effectiveness.

One of the key success factors achieved was the completion of specific/customised requirements to support each of the seven (7) critical elements; carried out in collaboration with DOE. The collaboration resulted in a consistent understanding between PETRONAS and DOE (as the Authority) on the elements’interpretation for implementation.

As a result, EMSR performance to-date is at satisfactory level with continuous improvements identified to sustain compliance with local regulatory requirements. This imparts PETRONAS’ commitment in upholding reputation as a responsible company in maintaining regulatory compliance on business operations, striving for operational excellence and supporting license to grow.

Introduction

Environmental sustainability is fundamental to PETRONAS’ present operations and future business growth.

76 Petroleum Today - October 2019

In order to have a proactive role to uphold environmental protection, mainstreaming of environmental matters has become the forefront in every stage of business phases starting from planning & development, throughout execution and up to decommissioning (or closure; i.e. may involve rehabilitation). In fact, environmental mainstreaming is currently used as strategic tool in achieving self-regulation1.

The objectives of environmental mainstreaming are to steer and embed the integration of environmental management priorities; i.e. risks identification & mitigation, and performance monitoring to drive operational governance, into business plans, development and operations. It is intended for the mainstreaming effort to influence decision making at all levels of organisation hierarchy, and within key operational phases of the company. In the long term, environmental mainstreaming will shape the right generative culture inculcated across assets’ life cycle that add value to operational excellence and growth.

The importance of mainstreaming has been recognised by DOE as the approach to instill operational discipline for regulatory compliance. In 2016, a Guided Self-Regulation (GSR) was introduced by DOE to assist regulated industries to cultivate operational self-regulation. This is achieved through application of GSR that focuses on key environmental areas such as air emissions, water and hazardous waste management.

Self-regulation is a long term goal required by DOE to strengthen environmental ownership, deliver excellence through environmental commitment and strive for environmental regulatory compliance at the organization

and/or operations’ premises.

depicted in the Figure 1.

With the objective to accelerate self-regulation culture, DOE had further directed GSR implementation by use of seven (7) environmental mainstreaming tool or critical elements governing environmental commitment, capability & resources; including communication to stakeholders. The seven (7) mainstreaming critical elements are:

As results of the mapping, it was found that in principle HSEMS was adequate in meeting DOE,s environmental mainstreaming expectations. Despite the adequacy of HSEMS, it is beneficial to have a more prescriptive requirement to be defined to ensure full compliance with DOE’s environmental mainstreaming expectations.

Therefore, PETRONAS’ technical standard titled Environmental Mainstreaming for Self- Regulations (EMSR) was established to provide clear and prescriptive requirements to be emphasised in each element during implementation as the demonstration of self-regulation.

1. Environmental Policy; 2. Environmental Budgeting; 3. Environmental Monitoring Committee; 4. Environmental Facility; 5. Environmental Competency; 6. Environmental Reporting & Communication; and 7. Environmental Transparency PETRONAS, in scoping the execution of EMSR, had adopted the expectation and tools provided by DOE in line with the Environmental Mainstreaming Directive. Additionally, PETRONAS had leveraged on the existing PETRONAS HSE MS to drive implementation effectiveness. As a prerequisite, mapping of the critical elements to the HSE MS had enable provision of technical standards whereby customisation to support EMSR was carried out for each of the seven (7) elements above.

The customization of technical standards basically specified the minimum technical requirements to meet the following objectives: a. Guide PETRONAS’ Malaysia operations to implement EMSR with clear measurements of effectiveness; b. Strengthen environmental compliance with the domestic regulations applied to Malaysia Operations; c. Standardise and/or prescriptive EMSR implementation practices (at minimum) within PETRONAS. Overview of EMSR Implementation Journey in PETRONAS PETRONAS had, in early 2016, initiated development of a Self-Regulation Framework by usage of HSEMS as the selfregulating tool. The intent then was to elevate the importance of environmental management through mainstreaming environment within the company. In the same year 2016, DOE introduced the GSR as the strategic supporting tool to be adopted for environmental mainstreaming.

Following GSR introduction, a Guidance Document on Implementation of Self-Regulation Initiative in Industrial Manufacturing Premises: Environmental Mainstreaming Tools was issued by DOE in April 2016 and revised in 2017. The document emphasized on the seven (7) environmental mainstreaming tools to be applied, which PETRONAS then mapped each element with the HSEMS. The process-chain that defines self-regulation framework is

The EMSR technical standard specifies the minimum technical requirements that guide PETRONAS’ Operations to demonstrate self-regulation, and to strengthen environmental regulatory compliance within Malaysia operations. The main purpose of the standard is to drive a common Environmental Mainstreaming implementation practices (at minimum) within PETRONAS to ease measurement of effectiveness. The scope covers all phases of work activities from development project to operation and maintenance, and up to decommissioning phase (as applicable) for PETRONAS’ owned facility operated in Malaysia only.

The value impact created from mapping of the seven (7) EMSR critical elements to the existing PETRONAS HSE MS had established how HSEMS could be applied to facilitate implementation effectiveness. Mapping of the two is as shown in Figure 2.

Figure 2 above featured the eight (8) drivers of PETRONAS HSEMS alignment to the seven (7) critical elements, and provided associated technical standards to be used by PETRONAS’ operating units (OPUs) as guidance and measurement in the implementation, monitoring and measurement of EMSR compliance.

Based on the alignment, PETRONAS’ operating units are required to demonstrate application of respective specific HSEMS drivers on-site. Ease of application is supported by an established integrated on-line system of HSEMS that would accelerate implementation and optimisation of resources.

PETRONAS believe that by way of integrating EMSR requirements, backed by an established on-line system, will facilitating effectiveness in implementation, monitoring and continuous review for compliance.

PETRONAS Technical Standard EMSR was completed and rolled-out in September 2016. All operating units are obligated to identify gaps against the technical standard requirements and developed the gap closure plan. In the spirit of self-regulations, OPUs conduct self-assessment

Petroleum Today - October 2019 77

independently and self-declared the status of compliance.

Effective January 2017, EMSR was officially implemented while gap closure actions were conducted in parallel. OPUs were given one (1) year to close identified gaps; primarily on administrative requirements.

Gaps closure status are closely monitored by GHSSE every 6th month within the first year.

By the 3rd year, which was 2018, verification of the compliance was conducted by PETRONAS using the established assurance system. It has been planned that moving forward from 2018, compliance verification will be carried out periodically. Figure 3 illustrates the EMSR implementation timeline and focused experience created.

Continuous engagement with DOE as the Authority was a key activity carried out throughout the implementation of EMSR in 2016 up to 2018. The engagement focused on clarification of the expectations, concurrence on PETRONAS’ approach for compliance and progress of implementation.

Achievements and Key Success Factors

One of the key success factors experienced in the EMSR implementation was development of specific technical requirements for each critical element; carried out in collaboration with DOE. The collaboration had delivered consistent understanding between PETRONAS and DOE on the measurement of compliance.

Additionally, the collaboration has also broadened insights on regulatory interpretation for compliance, and instill alignment to a common objective. This uplifts PETRONAS’ reputation as a responsible company on regulatory compliance, and support the efforts to strive towards optimum levels of operational excellence.

Throughout the phases of EMSR implementation, continuous communication & engagement with affected business and operating units were carried out. These had assisted in achieving consensus at large of targeted deliverables, and made available technical advice on mitigation of noncompliance.

To-date, all PETRONAS’ operating units have successfully implemented EMSR, which have assisted to identify, assess, manage and monitor risks/gaps for remedy. A verification assessment was also conducted to ensure the requirements of EMSR are fully met that otherwise the implementation gaps tracked for closure and continuous improvements.

In 2018, EMSR implementation delivered a tangible success at average of 93% compliance. Improvement actions are currently being addressed involving measuring value impact of environmental monitoring committee, adequacy of environmental competency, and availability of

78 Petroleum Today - October 2019

environmental facility. Illustration on EMSR delivery as per the seven (7) critical elements and based on mapping with HSE MS are highlighted in Table 1.

EMSR implementation had significantly improved operational compliance & initiatives related to pollution prevention and abatement. Performance monitoring of air pollution control system (APCS) and industrial effluent treatment system (IETS) were observed through proper management of environmental critical equipment; trending & analysis of performance data; and interval & consistent review of performance through Environmental Monitoring Committee. Waste minimisation effort in particular was tremendously observed. The success is a reflection of sustainable environmental practices in the company.

Collaboration between company and DOE has also been strengthened. By promoting self-declaration, transparency on managing environmental issues within PETRONAS and to DOE has increased. OPUs are now more open in highlighting compliance issues upfront, and continue to seek clarification and consultation with GHSSE or DOE to support closure of compliance gaps.

The above benefits could observed based on OPUs efforts to comply with the Environmental Quality (Clean Air) Regulation 2014, hazardous waste management and digitalisation of environmental monitoring data.

Conclusion

The integration of EMSR with PETRONAS HSEMS has proven to be a successful experience that facilitated effective EMSR implementation, monitoring and measurement within the company.

PETRONAS’ commitment to self-regulate has contributed to efficient environmental performance in operations against DOE enforced regulatory requirements. Indirectly, this contributed in shaping a stronger HSSE compliance culture simply through strengthening of personal accountability.

The implementation of EMSR has also strengthen collaboration with DOE in areas such as insights on regulatory requirements, opportunities to co-create improvements towards environmental sustainability and sharing of technical knowledge. Impact from these have demonstrated PETRONAS’ commitment in environmental mainstreaming that delivers long term value.

As a next step, there is a plan to expand the scope of EMSR to include the broader environmental risks such as climate change and biodiversity & ecosystem services; and consider impact on social performance.

The wider integration as such will facilitate value creation beyond compliance that support business growth.

REFERENCES Department of Environment. (2016). Guidance Document on Implementation of Self-Regulation Initiative in Industrial Manufacturing Premises: Environmental Mainstreaming Tools. Putrajaya: DOE Department of Environment. (2017). Environmental Mainstreaming Directive: Explanatory Notes on Environmental Mainstreaming. Putrajaya: DOE PETRONAS Environmental Mainstreaming for Self-Regulation (Malaysia Operations) (Revision: 2016) (Department of Environment, 2017) PETRONAS (Petroliam Nasional Berhad). (2018). Sustainability Report 2017 – Moving Forward Together. Kuala Lumpur: PETRONAS

Figure 1—Process-Chain of Self-Regulation Framework

Figure 2—Mapping of DOE Environmental Mainstreaming Tool with PETRONAS HSE MS

Figure 3—The Journey of PETRONAS EMSR

80 Petroleum Today - October 2019

Petroleum Today - October 2019 81

Egypt Gas,

offshore maintenance

Why offshore maintenance matters?

pipework, all crammed in a very

salts, guano (bird droppings), ultra

tight and congested deck footprint.

violet (UV) light, well fluids, vibration

Offshore oil and gas structures known

The most widely used material for

and pressure results by time to corrosion

as floating production, storage and

construction for these assets is carbon

of these materials of construction. The

offloading vessels (FPSO), and fixed

steel, with lesser amounts of stainless

most common method for limiting

platforms, are usually very complex

steel (different grades), galvanized

corrosion and metal loss is the use of

assemblies of fabricated steelwork,

steel and some nonferrous metals.

protective coatings.

metalwork,

and

Operating around the clock in a marine

members,

environment with the continuous

Why Egypt Gas?

tanks, valves, pumps, screens and

influence of heat, moisture, marine

We provide a fully integrated service

equipment,

pressure structural

vessels

84 Petroleum Today - October 2019

managed by a highly skilled team of experts to achieve all maintenance and shutdown support programs phases.

With decades of experience since 1988 and up till now with a milestone over 2,500,000 m² of painting activities and a lot of successful mechanical upgrading for offshore platforms, deck extensions and boat landings’ new

fabrication

and

installation,

providing critical support to offshore assets to most of sister companies in Egyptian Petroleum sector. We have the capability to maintain safety and integrity while maximizing efficiency for our customers as our aim is to minimize cost, extend asset life and value and maintaining safety first at all times. In addition to its experienced personnel, Egypt Gas has a fleet of modern equipment supported by the latest technologies to ensure that our customers receive a reliable and efficient service that can react to the changeable environment in which we work.

(protective coating and surface preparation).

2. Helidecks (chopper landing pads) rehabilitation program.

3. Mechanical installations (Deck extensions, drainage systems, repair of production lines, riser clamps install, boat landings fabrication equipped with rubber finders, FBSO

storage tanks repair and upgrading).

4. Lighting installations for offshore facilities.

5. Polyethylene submerged pipe lines for offshore production needs.

6. Thermal insulation for production pipe lines, valves and equipment.

7. Grating (Galvanized – FRP) with all related accessories.

Our multi-skilled technicians and specialized engineers’ are capable to work across multiple services in order to provide integrated solutions to person on board issues, reduce man hours and increase efficiency.

Egypt gas believes that its true fortune lays in its highly skilled and trained manpower, as the priority is always for the commitment to occupational Safety, Health and Environmental (HSE)

requirements

according

to

the

and

criteria,

manners

that

guarantee the safety of the Company’s Manpower and the prevention of any possible injuries or accidents.

Egypt Gas Scope of work: 1. Assets integrity and preservation

Petroleum Today - October 2019 85

Interview With

Mohamed Agamy

Managing Partner of Links & Gains Law Firm Petroleum Today would like to know insights from you about the management biography and the idea behind making such a firm.

Actually, my background has rounded as being a trilingual lawyer and driven professional legal professional. I have had a long years of experience with proven track record over nowadays 16 years of leading successfully international legal transactions. In addition to that have a diverse business areas of expertise across North Africa and Middle East; particularly for Energy, Oil & Gas, and Renewables.

Prior to establishing Links & Gains, I filtered the legal market to sort out a firm that work in deep experience with the industries, and to know in exactly what is the client need. I would say that what keep us different is that; we fully appreciate our clients’ necessities of being driven by time-deadlines and urgency. Our main objective is to provide our clients the best legal solutions, the competitive edge, representation available and at a reasonable cost. We pride ourselves on cementing long-term relationships with the primary focus on client success.

Thus, we are proud of the high legal conduct and ethical standards that have been established by our firm policy and the tradition of excellence that we work to maintain.

We are eager to know the services and what links and gains can do for the oil and gas sector.

major local and international transactions in different areas of practice and business sectors as: Dispute Resolution (Arbitration & Litigation), advisory for International Foreign Investment, Corporate & Commercial laws, Merge & Acquisition, Insurance, Intellectual Property and Taxation.

However, as for our specialization for the Oil & Gas; we provide top class counseling on the full range of potential legal matters and advisory on the “Upstream” onshore and offshore exploration and development projects, also the “Downstream” including transportation and storage, upgrading and refining.

Our expertise also extends with deep knowledge to the Liquefied Natural GAS (LNG) and the “Midstream” projects relevant to pipelines development.

Links & Gains is a full services law firm provides professional legal services, qualified to provide such services under the Egyptian Law, and with outstanding track records in advising

How do you see the market of the oil and gas nowadays in Egypt?

I would see that much of the oil and gas companies has survived an especially tough few years ago with a lot of legal

88 Petroleum Today - October 2019

struggles passing by finance, exploration issues, lack of corporate structure and some others faced Arbitration cases. Nowadays, I would say that the sector is like born again due to the Gas explorations in the North Mediterranean sea, plus the new Oil concession Agreements in the Red Sea as well.

It has been difficult to make strategic decisions and plan for the future. However, the sector beginning to emerge from its upheaval. If there is hope on the horizon, we must, remain mindful of the legal risk.

And when it comes to the future, companies will need to examine the role that digital technologies can play in improving their performance. Digitization should be a lever for innovation that improves productivity and efficiency in the field. From a management perspective, now is the time to recruit new talent from pools of highly capable men and women, casting a net in a range of global regions. Oil and gas companies need to engage with these recent gradu-

ates because they can provide the new ideas that will make the future easier to navigate. With so much innovation in the sector, and just it needs a clear and attractive story line to do so.

What are the legal problems that can occur in the oil and gas companies on their different aspects; service companies, E&P companies and contractors?

This is actually a very wide question, and answering on the aspects you described might take a very long time, however I will try to simplify with describing the most common legal issues arising under the different categories.

For example when we talk about the upstream companies which are mostly foreigners and/or multinational organizations, the most common issues are under the settlements of their dues from the cost recovery under the concession agreement, also the farm in and out negotiations, some others related to the receivables and on top of it the decommissioning nowadays.

For the services companies and EPCs I would conclude the legal issues parked as usual in their contracts for onshore and offshore projects; some companies has a lack of hiring a specialized lawyer who can identify the potential risks in the terms and conditions. So, they are of knowledge how to handle matters by set of procedures of force majeure, performance-related issues, indemnity insurance provisions, regimes, change orders, defaults and remedies and also termination.

However, on above of all the environmental issues and HSE matters that perform the usual risks that require a very strategic and efficient persuasions.

not only for contracts and lawsuits but mainly for risk decisions, and identifying the legality of new opportunities as well. Our legal methodology is to clarify the pros and cons of matters with highly analytical scenarios that support the decision taker to pick the right directions based on the clarity of the risk assessment methods.

We also have a deep industry knowledge to handle all legal aspects of a project from inception to completion, including but not limited to: Production Sharing Agreements, Concession agreements, Building and financing of pipelines, Developing and financing LNG projects, conventional and unconventional gas, refinery and petrochemical projects, gas-to-liquids (GTL) facilities and marine transportation, Growing and protecting intellectual property and brands, Dispute resolution in every forum, Full range of agreements with contractors and third parties, including EPC and other construction agreements, Completing strategic acquisitions and Joint venturing and also for compliance and governance issues as related to FCPA, Anti Bribery Act and European Union Conventions.

We would like to have your future plan steps for going forward into the market.

I would say that Links & Gains is tak-

ing the lead on advisory for the sustainable development goals of Egypt vision 2030 and Integrated with the National Sustainable Energy Strategy towards 2035. While, on the international base we are supporting the conventions of the Climate Change and the UN SDGs as well, for instance the climate change pledge agreement and Paris Convention whereas Egypt is a ratified country. The Oil & Gas Companies in Egypt should follow a certain new rules and regulation when such environmental regulations applied particularly for the energy efficiency and carbon foot print reporting scheme.

Of course, we would like to hear more about your services in other disciplines and consider this point as an open space for adding recent achievements and announcements.

We are actually delighted that we be appointed by the IR Global as an exclusive member in Egypt for the Energy law, this also happened in parallel to another selection by the Advisory Excellence, UK for 2019/2020.

Whereas, I’m really confident that this global achievement step would be an extra added value to provide our clients and partnerships a top class of legal services and beyond ....

What are the different solutions that can links and gains do for the both the local and international oil and gas companies?

We at Links & Gains usually takes alternative legal commercial approach not followed by traditional law firms or costly consultancies. We are much closed to our clients advising them

Petroleum Today - October 2019 89

ADMASCO OIL FIELD SERVICES CO. Established in Egypt in 1982 as a free zone company under the investment law number 8 / 1997 Admasco committed to facilitate its esteemed customers with professional services, quality products, timely deliveries and excellent pre and post-sales supports through highly qualified Admasco team and pioneered principals.

CAMTECH Manufacturing FZCO API 6D, API 6A, API QI Valves Manufacture of Ball, Gate, Globe, Butterfly, Check and Pigable Valves NOV Process & Flow Technologies US, Inc. Choke Valves NOV-MD Totco Rig Instrumentation, Gauges, Recorders & Mud Monitoring Systems Hoffer Flow Controls, Inc. Turbine Flow Meter for Fluid, Gas, Water and Steam TRANSNEFT Diascan JSC-Russia Smart pigs in-inspection tools with diameters from 6»-48» USK Series(WM)-MSK Series(MFL)-(MFL+TFI)-(MFL+WM+CD)-MSK Series(TFI)

CHELPIPE GROUP SAWL Pipes & Accessories from 20 in. up to 56 in.

Rustavi Metallurgical Plant Carbon Steel Seamless pipe up to 16» JVS Flow Control Chock Manifold- Chokes & Gate Valves Drilling equepment repair and recirtification.

Maitech International, Inc. - USA Line Pipes, Casing Pipes & Pipe Fittings – Stockiest

Admasco Work Shop ISO / IEC 17025 & 4126 - 1 Accreditation for Pressure Gauges, Transducer, Safety Relief Valves and Hydrostatic Test for Hoses, Pipes, Valves, BOPs & Vessels according to ASME B31.3 - ISO 1402 - API 570 - API 598 - API 7K & 16C – API RP 53 and API 510

www.admasco.com.eg

Main Office: 28 Rd. 270, 4th Sector, New Maadi, Cairo, Egypt Tel.: +202 27025224 Fax: +202 27023290 E-mail: admasco@admasco.com.eg Free Zone Warehouse: Free Zone Amerya - Alex.

Work Shop Yard: Plot 17S, Industrial Zone, Investment Land, Qattamia, Cairo, Egypt

MYDESIGN

TripleFast Middle East Ltd. Manufacturer of a Bolting Gaskets, Seals and Machined Components

Hady Meiser Egypt is an Egyptian German joint venture investment that manufacture bar gratings with high quality and prices than their imported which used in various fields as petroleum companies – Power stations – Cement companies – Fertilizers company , spiral stairs and slitting coils.

Perpendicularly and anchored securely can carry substantial load.

Hady Meiser grating is acknowledged by trade specialists to be one of the best product of its kind in Europe , It›s a fair assessment, we feel and part of the reason is undoubtedly the committed work of our planning department and our reliable delivery dates.

and twisted cross bars 5 mm. or 6 mm in addition to the possibility of manufacturing the serrated grating which are specially made for the petroleum companies

What is the gratings ?

Try asking non- experts what a grating is « a grating ?» , most of them will reply « a grating is a kind of floor on which you can stand safely, but when you look down , you get the feeling you›re standing in mid-air.

our gratings enjoy various specifications they have different sizes of bearing bars starting from 25x 3 mm . up to 50 x 5 mm and fences .

Slitting coils : In addition that it has been inserted a new production line for rod slitting coils ( black-galvanized – hot – cold ) in thickness starting from 1 m up to 4 mm

Mr. Taha Abou Rabia General Manager

MYDESIGN

Indeed , more than 80% of any grating does exist of holes, we simply exploit the fact that a strip of metal positioned .

Gratings Specification :

Head office : 2 Asma Fahmy St,Heliopolis, Cairo,Egypt Tele : (+202)24175822 - 22903879 Fax : (+202 ) 26903694 - 22919273 E-mail : Trabia_meiser@hadymeiser.com website: www.hadymeiser.com

Factory : ElShrouk Industrial Zone – Khanka – Kaiobia Tele : +2 02 44564091 - 2 Fax : +2 02 44564093 - 44698212 Mobile : 01001726068 – 01144877633 01276798800 – 01001726135 E-mail : trabia.meiser@gmail.com

Industry At A Glance World liquid fuels production and consumption balance Million barrels per day

Annual change in world liquid fuels consumption Million barrels per day

98 Petroleum Today - October 2019

by: Ali Ibrahim

OPEC Crude Oil Production

January-19 February-19 March-19

April-19

May-19

June-19

July-19

August-19

Crude Oil Prices

NYMEX Natural Gas Prices USD/Million BTU

Petroleum Today - October 2019 99

Egypt’s Gas Production

Egypt’s Oil and Condensate Production

Egypt’s Geographical Rig Count

100 Petroleum Today - October 2019

Technology Applications What benefits can 3D flame and gas mapping bring to a hazardous facility ?

Inherent within the very nature of the energy industry, the hazards associated in refining oil and gas present a number of risks. One of the prominent and well documented risks is the potential for fire or explosions as a result of a break in containment. To combat this, facilities incorporate a combination of Flame and Gas Detectors to detect events before they become unmanageable.

w

By: James McNay - Director of Consultancy and Engineering at Micropack (Engineering).

ith the increase in prevalence of flame and gas detection technologies in the 1980s, and with technological improvements improving to this day, deciding where to locate these detectors based on the hazard they are intended to mitigate became far more open to scrutiny.

History of F&G mapping The question was, and still is, regularly posed: ‘How many detectors do I need, and where do I put them?’ A fair question in the context of a processing facility where traditional detection codes are simply not applicable. Placing heat detectors on a grid is intuitively not adequate for external processing facilities exposed to harsh environments like the North Sea. How, therefore, can we adequately position flame and flammable gas detectors, such that target fire sizes and gas clouds of concern can reliably, and verifiably, be detected?

As a result of this challenge, Micropack introduced the first F&G modelling assessment software in 1989. This technique was then developed by Micropack, BP and Shell, with Shell coining the term widely used today – ‘F&G Mapping’.

Just after the turn of the century, Shell

104 Petroleum Today - October 2019

and BP formalised their practices in to their own internal guidance documents, detailing methodologies against which F&G Detection systems should be designed where national/ international codes are not applicable.

In 2005, Micropack introduced the concept of F&G Mapping to the ISA84 committee, which later rolled out ‘ISA TR84.00.07 Guidance on the Effectiveness of Fire and Gas Detection’. Since then, Micropack

James McNay

has continued to innovate in the field of F&G Detection Design through software development and refinement of best practices in relation to F&G Detection Design.

Risk based coverage analysis There are countless potential ways in which a fire or gas release can impact on a facility.

Certain processes present the potential for a gas jet/ liquid spray fire where pressures

F&G Mapping is particularly important where conditions can be variable and unpredictable.

exist in the stream, flash fires/ fireballs are credible, in addition to Boiling Liquid Expanding Vapour Explosions (BLEVE) and hydrocarbon/ chemical pool fires.

Gas releases can present an explosion hazard in congested areas and a hazard to adjacent areas through gas migration, as well as providing the potential for toxic gas release where toxic constituents exist within the stream. It is therefore critical that an appropriate methodology is applied to ensure the detector distribution will detect a fire or gas release at an acceptable stage along the event timeline to provide effective mitigation measures.

F&G Mapping allows the designer to position flame and gas detection devices within the facility and assess the coverage afforded by the system.

This is automatically correlated against pre-specified targets that the system must achieve. An example of such targets applied for a flame detection system can be seen in Table 1.

These targets allow the designer to position flame detectors in such a way that small fires are detected early in high risk areas, whereas low risk areas allow the fire to grow to a more substantial fire size before activating any automatic actions (i.e. release of deluge/ shutdown of equipment).

This meets the philosophy of risk/ goal based F&G detection design. One of the greatest features of such an approach is the ability to optimise the detection system and demonstrate this optimisation (providing the fewest number of detectors while meeting the predetermined detection targets).

The application of effective technology is equally critical to system optimisation, in addition to reliability of the detection system during operation. The strengths and limitations of each technology must be

Figure 1: iVFD detection footprint to 1 ft² n-heptane pan fire on default sensitivity (60m with 120º field of view).

Figure 2: Triple IR Detection footprint to 1 ft² n-heptane pan fire on default sensitivity (30m with 90º field of view).

noted and accounted for within the design to ensure appropriate technologies are applied to the specific hazards of the facility. Each device will have its own unique ‘footprint’ which should be accurately represented in the mapping, as this can have a significant impact on the results of the assessment and the subsequent analysis of adequacy.

Figures 1 and 2 show the difference in

detection footprint between an intelligent visual flame detector (iVFD) and a triple IR flame detector. Comparisons show that on facilities where visual detection is used, the detector count can be reduced by up to 30%.

If we, therefore, are to optimise our layout, the detection technology selected will have a significant bearing on the results.

Change Management/ Operations F&G Mapping does not only provide benefits during the design phase. The benefits of F&G Mapping can also be observed in a number of ways throughout the operational phase. The first relates to design in that as the process changes through redundancy/ replacement of old equipment (or through the introduction of new process or simply through alteration in the processing

Petroleum Today - October 2019 105

Detector Contributions

FIRE DETECTOR DETAILS (Page 1 of 1) Tag

Type

Tech

Status

Voted

Detx,Y,ALD(m)

Pan/Tilt (deg)

Individual

100N

200N

> 200N

FDS001

MP_FDS301

Visual

Exists

34.171

39.674

4.003

-52

0

49.9

90.3

67.2

26.8

FDS002

MP_FDS301

Visual

Exists

34.198

22.639

3.768

+141

0

25.1

96.9

76.2

36.7

FDS003

MP_FDS301

Visual

Exists

22.198

17.606

3.768

+143

+15

14.2

96.9

74.7

43.3

FDS004

Drager_FL5000

Visual

Exists

5.020

22.167

3.506

0

+15

57.2

92.0

62.2

26.2

FDS005

CD_F_301

Visual

Exists

5.020

39.730

3.475

-138

+15

39.2

96.2

67.1

36.5

FDS006

CD_F_301

Visual

Exists

45.459

12.138

5.333

+147

+15

59.7

91.0

63.2

26.0

97.0

78.2

49.0

ALL DETECTORS

Figure 3: Example Flame Detection Contributions.

conditions), F&G Mapping can allow quick and easy revalidation of the design to ensure coverage is not degraded. This also shows if further optimisation can be achieved.

Without F&G Mapping, designs carried out years before can be difficult to revalidate if the responsible engineer has moved on.

Knowing the intentions behind detector placement can often be difficult to decipher.

With F&G Mapping, however, the targets are detailed. These targets can be revalidated, with the coverage then recalculated to make sure the original design intent maintains its credibility.

Another benefit pertains to real time operations. One of the primary deliverables

of an adequate F&G Mapping study is detailed detector contributions.

An example of these contributions can be seen in figure 3. These contributions show the individual percentage contribution of the volume from each detector, but also, critically, the percentage lost should that detector be taken out of service.

Knowing the degradation of coverage when a specific detector is removed can be useful in design as it can help remove the detectors that do not contribute as effectively as possible. Crucially though, if a facility (which can have upwards of 200 flame detectors) has, for example, five detectors in fault at one time, this can provide a

It is important that flame detection coverage assessments show the percentage of the volume covered by a single device as well as the percentage of the volume covered by multiple devices.

Any assessment should also highlight any blind spots.

106 Petroleum Today - October 2019

difficult decision for the maintenance team as to where to start. A quick look at the detector contributions, however, can direct them to the most important detectors that are out of service, and allow for that crucial maintenance optimisation function.

Conclusions One of the most important factors in the design of safety critical systems is ensuring the design has a suitable number of sensors to achieve the required safety function, without significant over engineering. F&G Detection is no different, but a little more complex. F&G Mapping provides designers with the methodology and tools to review detection coverage against pre-determined targets, and ensure a suitable and optimised system is commissioned. There are countless other factors to be considered including implementation of an appropriate methodology based on the application, application of engineering judgment as to what adequate coverage looks like, and the application of appropriate detection technology. Pulling all these factors together has been proven to reduce costs of the system significantly and streamline the change management process throughout the operational phase of a facility.

F&G Mapping also provides the significant benefit of maintenance optimisation, which can save money and potentially lives. Where multiple detectors are in fault, maintenance engineers can quickly and easily verify the devices that are the more safety critical, and focus their efforts on bringing them back online.

For more information, go to www.micropackfireandgas.com

‫فاعلية التصميمات القديمة ألنظمة الحريق‬ ‫والتقني���ات المس���تخدمة وكيفي���ة إختي���ار‬ ‫أجهزة الكش���ف المناسبة ووحدات التحكم‬ ‫ول���ذا تم تطبيق تقني���ة ‪ 3D Mapping‬وهى‬ ‫بإختصار محاكاة حقيقية لمواصفات أجهزة‬ ‫الكش���ف عن الغاز والحري���ق وعمل محاكاة‬ ‫إفتراضي���ة ثاثي���ة األبعاد على س���يناريوهات‬ ‫تس���ريب غاز وحرائ���ق وهمية عل���ى طبيعة‬ ‫الموق���ع وقي���اس كفاءة التصمي���م وتوزيع‬ ‫األجهزة للوصول بالتصميم من خال دراسة‬ ‫واقعية ثاثية األبع���اد وإختيار أماكن تركيب‬ ‫وإعداد أجهزة الحساس���ات بما يضمن سرعة‬ ‫اإلس���تجابة والكش���ف المبكر ع���ن حوداث‬ ‫التس���ريب ف���ي مراحلها األولي���ة بما يضمن‬ ‫س���رعة اإلس���تجابة الفائقة بم���ا يمنع وقوع‬ ‫الح���وادث الجس���يمة والحفاظ عل���ى األفراد‬ ‫والمع���دات والدراس���ات الحديث���ة أك���دت أن‬ ‫األنظم���ة القديم���ة ف���ي منطقة مث���ل بحر‬ ‫الشمال بالمملكة المتحدة في المتوسط‬ ‫ال تزيد فاعليتها عن ‪ %30‬وهى نس���بة تغطية‬ ‫ضعيفة يمكن ق���رءاة مقال كام���ل باللغة‬ ‫اإلنجليزية في نفس العدد‪.‬‬ ‫ما هى أهم الحلول التكنولوجية التي‬ ‫تقدمها الشركة في قطاع البترول؟‬ ‫تركز الشركة على تقديم حلول متكاملة‬ ‫ترى الصورة الكاملة – فنقدم تصميم حديث‬ ‫ألنظم����ة الحري����ق باس����تخدام ‪3D Mapping‬‬ ‫بالتع����اون م����ع ‪ Micropack UK‬نقوم بتوريد‬ ‫أنظم����ة متكامل����ة للكش����ف ع����ن تتضمن‬ ‫كواش����ف الحري����ق والغ����از من خال ش����ركة‬ ‫‪ Honeywell‬وقد قامت الشركة بتدريب عدد‬ ‫من المهندس����ين في الخارج لتقديم خدمات‬ ‫الصيان����ة واإلص����اح بس����رعة وكف����اءة عالي����ة‬ ‫لتقدي����م خدم����ات متكاملة م����ن التصميم‬ ‫والتوري����د والتركيب والصيان����ة ويمكن ربط‬ ‫األنظمة الحديثة الخاص����ة بنا بأنظمة اإلطفاء‬ ‫التلقائي أو أنظمة التحكم ‪.PLC/ESD‬‬ ‫أراك تتح���دث بمنتهي الثق���ة عن حلول‬ ‫تكنولوجية متقدم���ة ولكنها بالتأكيد‬ ‫مكلف���ة وغالي���ة ج���دا وال تس���تطيع‬ ‫الش���ركات ف���ي مص���ر تحم���ل أعب���اء‬ ‫التحديث؟‬ ‫اش���كرك لهذا الس���ؤال الواقعي والمهم –‬ ‫أوال ً الثق���ة تأت���ي من أننا بالفع���ل نجحنا في‬ ‫تطبيق تلك التقنيات مع كثير من شركات‬ ‫القطاع في مصر وقد رأيت وعملت بنفسي‬ ‫عليها خ���ال عملي العام‪ ،‬ثاني���ًا وهو األهم‬ ‫أنن���ا نجحنا بالفع���ل في التطبي���ق من خال‬ ‫مهندس���ين مصريين تم تدربيه���م بالخارج‬ ‫ف���ي تقليل أعب���اء التكلفة الكبيرة نس���بيًا‬ ‫إل���ى ح���د مناف���س ج���دا لألنظم���ة القديمة‬ ‫ولألمانة الش���ديدة التكلفة الرأس���مالية قد‬ ‫تكون أعل���ى قلياً وبنس���بة بس���يطة جدًا‪،‬‬ ‫ولك���ن درج���ة األم���ان واإلمكاني���ات ال تقارن‪،‬‬ ‫كما أن التكاليف التشغيلية أقل بكثير جدًا‬ ‫من األنظم���ة القديمة وس���وف أعطيك مثاً‬ ‫بس���يطًا إلى يومنا هذا يتم توريد وتركيب‬ ‫نفس األنظمة القديمة في أنظمة التحكم‬ ‫ف���ي الحريق التي تم تركيبها من عش���رات‬ ‫السنوات في المش���اريع الجديدة التي يتم‬ ‫إنش���ائها الي���وم – مث���ال ذلك اإلص���رار على‬

‫تركي���ب أنظم���ة تحك���م الحري���ق بالنظام‬ ‫المعن���ون ‪ Addressable Fire alarm‬خاص‬ ‫بأنظمة الس���امة الخاص���ة بالمباني وليس‬ ‫لألغراض الصناعية والتي تتطلب الحد األدنى‬ ‫أن يك���ون ‪ SIL 1‬أو ‪ SIL 2‬طبقًا لمعايير إدارة‬ ‫س���امة العمليات الحديث���ة وتوصيل أجهزة‬ ‫كواش���ف الغ���از والحريق على نظ���ام حريق‬ ‫معنون هو من قبيل إضاعة الوقت والموارد‬ ‫ف���ي أنظمة قديم���ة ثبت فش���لها التام في‬ ‫اإلتص���ال والتوافق م���ع القواني���ن والمعايير‬ ‫العالمي���ة وكذل���ك المش���اكل الناجمة عن‬ ‫الصيانة والتشغيل وكمية اإلنذرات الخاطئة‬ ‫والتي تكلف توقف وخس���ارة اإلنتاج أو ال قدر‬ ‫اهلل أعط���ال في النظام وع���دم القدرة على‬ ‫كشف األحداث الطارئة مبكرًا‪.‬‬ ‫اود ان اوض���ح ان االنظمة القديم���ة التي يتم‬ ‫العم���ل بها الي االن لن يك���ون لها قطع غيار‬ ‫بعد فت���رة وجيزة نتيج���ة ان معظم مصانع‬ ‫انت���اج تلك قط���ع الغي���ار س���وف تتوقف عن‬ ‫انتاجه���ا الن ه���ذه ال انظم���ة س���وف تصب���ح‬ ‫‪ obsolete‬مم���ا س���يترتب علي���ه تغيير تلك‬ ‫االنظم���ة اجباريا بعد ذلك و ل���ذا فنحن نقدم‬ ‫تكنولوجي���ا تمث���ل المس���تقبل األح���دث‬ ‫واألفضل في الحفاظ علي سامة العمليات‪.‬‬ ‫أخي���را – نحن نقدم ضم���ان يصل الي خمس‬ ‫سنوات في بعض األحيان‪.‬‬ ‫ه���ل من أفكار أو حلول خ���ارج الصندوق‬ ‫تس���تطيع ش���ركة إس بي أس تقديمها‬ ‫للمس���اهمة ف���ي التطوي���ر والتحدي���ث‬ ‫لشركات القطاع ؟‬ ‫بالتأكي���د – كم���ا اش���ارت مس���بقًا – تهدف‬ ‫الش���ركة إل���ى تطوي���ر التع���اون م���ع كافة‬ ‫ش���ركات القط���اع ولكنن���ا نول���ي أهتمامًا‬ ‫خاصًا جدًا لش���ركات القطاع العام وقد أثمر‬ ‫ذلك ع���ن توقيع مذك���رات تفاه���م وتعاون‬ ‫مش���ترك مع عدة ش���ركات لتقدي���م كافة‬ ‫خدمتنا من خال ش���ركات القط���اع – مثال‬ ‫ذلك شركة صان مصر ممثلة في مهندس‬ ‫محمد ش���يمي وتم توقيع مذكرة تفاهم‬ ‫لدراس���ة تطوي���ر وتحديث أنظمة الكش���ف‬ ‫المبك���ر ع���ن الحري���ق والغاز في ش���ركات‬ ‫القطاع العام والمشاريع الجديدة‪.‬‬ ‫تقوم الش���ركة أيضًا بتوفير تمويل خارجي‬ ‫بالدوالر لمش���اريع التحديث والتطوير وعدم‬

‫تحمي���ل ش���ركات القط���اع أي أعب���اء مالية‬ ‫دوالري���ة والدف���ع بأنظمة متعددة وميس���رة‬ ‫وف���ي إطار ح���رص الش���ركة عل���ى التدريب‬ ‫الواعي ورفع الكفاءة الفنية قامت الشركة‬ ‫بتنفي���ذ العديد من برام���ج التدريب الخارجية‬ ‫عل���ى المش���اريع الجديدة بم���ا يضمن حين‬ ‫التشغيل والصيانة وبدون تحميل الشركات‬ ‫أي أعباء أضافية‬ ‫هل تملك الشركة مركزا للبحث والتطوير؟‬ ‫يوج���د لدينا مرك���زا للبح���ث والتطوير في‬ ‫المق���ر الرئيس���ي للش���ركة بهيوس���تين‬ ‫كما نجري العديد م���ن األبحاث والتطبيقات‬ ‫الحديث���ة ف���ي مج���االت الحل���ول الرقمية ال�‬ ‫‪ Digitalization‬ألنظم���ة الس���امة – كم���ا‬ ‫حصلت الش���ركة مؤخرًا عل���ى إعتماد ال�‪UL‬‬ ‫األمريكية ألحدى منتجات مكافحة الحريق‪.‬‬ ‫كيف تس���تثمر إس بي إس في مجالي‬ ‫البح���ث والتطوي���ر لتقدي���م التقني���ات‬ ‫والحلول الحديثة ؟‬ ‫نؤمن بأهمية البح���ث والتطوير في تقديم‬ ‫تكنولوجيا جديدة لمواكبة كل جديد وإنتاج‬ ‫حل���ول حديث���ة ونس���تثمر في إع���داد أبحاث‬ ‫جديدة تهدف للتكامل في مجال الكش���ف‬ ‫المبكر وتطبيقات الحلول الرقمية والذكاء‬ ‫الصناعي ودمج أنظمة الكشف المبكر عن‬ ‫الحرائ���ق والغاز باس���تخدام أح���دث التقنيات‬ ‫كم���ا نش���ارك ف���ي المؤتم���رات العلمي���ة‬ ‫الدولية للتع���رف على األبح���اث الجديدة في‬ ‫مجال السامة والوقاية من الحوادث‪.‬‬ ‫هل للشركة أي نشاطات في المسؤلية‬ ‫المجتمعية في داخل مصر؟‬ ‫نق���وم ب���دور حيوي ف���ي هذا المج���ال حيث‬ ‫نمارس تلك المسئولية – واتشرف بعضوية‬ ‫وتأس���يس جمعية خيرية غي���ر هادفة للربح‬ ‫تس���مى ‪ -‬اصنع حلمك – ته���دف إلى تدريب‬ ‫الش���باب ف���ي المناط���ق النائي���ة وتقدي���م‬ ‫خدم���ات إجتماعي���ة مجاني���ة إل���ى جان���ب‬ ‫دورالتوعية التي تقوم به الش���ركة بشكل‬ ‫مؤسس���ي عاوة على أن نش���اط الش���ركة‬ ‫نفسه يتسم بالمسئولية اإلجتماعية حيث‬ ‫هدفنا األساسي الحفاظ على صحة وسامة‬ ‫األفراد ومنع الحوداث الكارثية المؤثرة على‬ ‫المجتمع المدني المحيط بشركات البترول‬ ‫وفي نطاقات المدن‪.‬‬

‫‪13 Petroleum Today - October 2019‬‬

‫الدكتور ميشيل مالك العضو المنتدب لمجموعة ‪:SBS Pro-Tech‬‬

‫نهدف لتطوير التعاون مع كافة شركات البترول‬ ‫ونحلم بخلوها من الحوداث واإلصابات‬ ‫تقدم ش���ركة إس بي إس للمشروعات‬ ‫والتكنولوجي���ا أح���دث أنظمة الس���المة‬ ‫المتكامل���ة‪ ،‬وتعد من أحدث الش���ركات‬ ‫العالمي���ة في مج���االت حلول الس���المة‬ ‫المتكامل���ة‪ ،‬كم���ا تنفذ الش���ركة عددًا‬ ‫من المشروعات الكبيرة األن في مصر‪،‬‬ ‫وتولي إهتماما خاصا بقطاع البترول‪.‬‬ ‫مجلة بتروليم ت���وداي التقت بالدكتور‬ ‫ميشيل مالك العضو المنتدب لمجموعة‬ ‫‪ SBS Pro-Tech‬ف���ي مص���ر للتع���رف على‬ ‫المزيد فكان الحوار التالي ‪:‬‬ ‫ف���ي البداية ن���ود التعرف على مس���يرة‬ ‫عمل سيادتكم ؟‬ ‫ب���دأت العمل بقط���اع البت���رول المصري من‬ ‫خ���ال ش���ركة الفرعوني���ة (جابكو س���ابقا)‬ ‫بحق���ول حاب���ي بورس���عيد ع���ام ‪ 1999‬أي‬ ‫منذ‪20‬عام���ا تقريبا‪ ،‬وانتقلت إلى جابكو في‬ ‫‪ 2002‬للعم���ل ف���ي منطقة خليج الس���ويس‪،‬‬ ‫ث���م ف���ي ‪ 2006‬انتقل���ت للعمل بش���ركة‪BP‬‬ ‫العالمية من خال مشروع سقارة في خليج‬ ‫الس���ويس‪ ،‬وف���ي‪ 2010‬انتقلت إلى الش���ركة‬ ‫البحرانية لمش���تقات الغاز ولظروف الهجرة‬ ‫للوالي���ات المتح���دة اس���تقلت م���ن قط���اع‬ ‫البت���رول‪ ،‬واتجه���ت للعم���ل الخ���اص بعد أن‬ ‫اكتسبت خبرة واسعة في مجال التشغيل‬ ‫والعملي���ات والصيان���ة وإدارة المش���روعات‬ ‫وخصوص���ًا تحدي���ث أنظم���ة الس���امة‬ ‫بالمشروعات الجديدة‪.‬‬ ‫ماه���ى اإلنج���ازات الت���ي تحقق���ت خالل‬ ‫عملك بالقطاع؟‬ ‫بفض���ل اهلل وزمائ���ي ف���ي العم���ل ودع���م‬ ‫رؤس���ائي على مدى عملي مديرًا للسامة‬ ‫‪14‬عام���ًا متصلة حققنا أكثر م���ن ‪ 18‬مليون‬ ‫س���اعة عمل آمنة لم أرى إصابة عمل واحدة‬ ‫وال حري���ق في مش���روعات بلغ���ت تكلفتها‬ ‫الرأس���مالية ‪ 750‬ملي���ون دوالر وعملي���ات‬ ‫تش���غيل اس���تمرت س���نوات تلو السنوات‪،‬‬ ‫رأيت التكنولوجيا والمعرفة والتدريب وروح‬ ‫الفري���ق الواح���د تصنع الفارق م���ع‪ BP‬حققنا‬ ‫أفضل وحدة عم���ل في‪ 2010‬بدون حوداث ومع‬ ‫البحراني���ة حققنا أكثر من ‪ 8‬مايين س���اعة‬ ‫متصلة بدون حوداث وال إصابات‪.‬‬ ‫ماذا عن شركة أس بي إس للمشروعات‬ ‫والتكنولوجيا؟‬ ‫‪ SBS‬هي إختصار‪- Safety Boss Solutions‬‬ ‫هى رؤية عملية ومش���اركة خبرات لتطبيق‬ ‫حلول مدير الس���امة لمنع الحوداث والتنبؤ‬ ‫به���ا قب���ل وقوعه���ا‪ ،‬وكاف���ة الحل���ول التي‬ ‫نقدمها تركز بشكل رئيسي على التقنيات‬ ‫الحديث���ة‪ ،‬والت���ي رأيتها على م���دى عملي‬ ‫الس���ابق بالفع���ل تمنع الحوداث وتس���اهم‬

‫‪Petroleum Today - October 2019 12‬‬

‫بصورة كبيرة في خلق بيئة عامل آمنة‪.‬‬ ‫ش���ركة أس ب���ي إس ه���ى ش���ركة مصرية‬ ‫أمريكية – مقرها الرئيسي في هيوستين‬ ‫تكس���اس بالوالي���ات المتح���دة األمريكي���ة‪،‬‬ ‫وله���ا مقر بالمنطقة الح���رة في مدينة نصر‬ ‫ومق���ر إداري ف���ي المعادي الجدي���دة ويوجد‬ ‫لنا مكت���ب تمثيل بالمنطق���ة الحرة برأس‬ ‫الخيمة باإلمارات العربية المتحدة‪.‬‬ ‫وإنتقال���ي م���ن العمل الع���ام إل���ى العمل‬ ‫الخاص كان���ت حلم ش���خصي تحقق بحمد‬ ‫اهلل واألن لدي حلم أكبر لنقل كافة الخبرات‬ ‫الت���ي تعلمتها بعملي في القطاع إلى كل‬ ‫الش���ركات وأحل���م باليوم ال���ذي نحتفل به‬ ‫بتحقي���ق عام خالي من الح���وداث واإلصابات‬ ‫في كافة مواقع شركات البترول في مصر‬ ‫الت���ي اتمنى أن تصب���ح خالية م���ن الحوداث‬ ‫واإلصاب���ات وتعم���ل وفق���ًا ألح���دث النظ���م‬ ‫وتس���تخدم أفض���ل التقني���ات الحديث���ة في‬ ‫مجال الس���امة‪ ،‬والتي رأيتها وتم تطبيقها‬ ‫بالفعل في المش���اريع الحديثة التي عملت‬ ‫بها في مصر أو في الواليات المتحدة‪.‬‬ ‫ما ه���ى أه���م التحدي���ات الت���ي تواجه‬ ‫قطاع البترول في مصر حاليا ؟‬ ‫واحدة من أهم التحدي���ات التي تواجه قطاع‬ ‫البت���رول حاليًا هو التطبي���ق العملي على‬ ‫أرض الواق���ع لرؤي���ة معال���ي وزي���ر البت���رول‬ ‫والث���روة المعدني���ة المهن���دس ط���ارق الما‬ ‫وزير البترول لتحديث وتطوير قطاع البترول‬ ‫وخصوص���ًا تطبيق أحدث المعايي���ر العالمية‬ ‫ف���ي مج���ال الس���امة المهني���ة بم���ا يمنع‬ ‫اإلصاب���ات والوفي���ات والس���امة الصناعية أو‬

‫س���امة عمليات التش���غيل بما يمنع وقوع‬ ‫الحرائق وخسارة المعدات واألصول‪.‬‬ ‫كيف تس���اهم ش���ركة أس بي أس في‬ ‫تطوير وتحديث قطاع البترول وخصوصا‬ ‫أنظمة سالمة العمليات بصفة خاصة؟‬ ‫تتطابق رؤية الش����ركة م����ع توجهات معالي‬ ‫وزي����ر البت����رول والثروة المعدني����ة المهندس‬ ‫طارق الما في تحديث وتطوير قطاع البترول‪،‬‬ ‫وخصوصًا تطبي����ق أحدث المعايي����ر العالمية‬ ‫ف����ي مج����ال الس����امة الصناعي����ة وتس����عى‬ ‫الش����ركة جاهدة إلى أن نكون أفضل شركة‬ ‫تق����دم خدمات متكاملة للصحة والس����امة‬ ‫والبيئة تدع����م وتوفر «التميز التش����غيلي»‬ ‫“‪ ”OPERATIONAL EXCELLENCE‬لكافة‬ ‫عمائنا ونق����ل وتطبيق أحدث التكنولوجيات‬ ‫والتقنيات إلى كافة ش����ركات قطاع البترول‬ ‫المصري‪ ،‬ورفع درجة الوعي لجميع العاملين‬ ‫بنظم السامة الحديثة لتصل إلى كل عامل‬ ‫في القطاع‪.‬‬ ‫ه���ل تلق���ي لن���ا الض���وء عل���ى تقني���ة‬ ‫تكنولوجي���ا مح���اكاة ثالثي���ة األبع���اد‬ ‫للكش���ف المبكر ع���ن تس���ريبات الغاز‬ ‫وأنظمة كش���ف الحريق ثالثي األبعاد ‪3D‬‬ ‫‪Fire & Gas Mapping‬؟‬ ‫بع���د الح���وادث الكارثية األخي���رة مثل حادث‬ ‫‪ Deep Water Horizon‬تسريب غاز وزيت ثم‬ ‫حريق وح���دوث اإلنفجار والتس���ريب النفطي‬ ‫الكارث���ي ف���ي خليج المكس���يك ف���ي ‪،2010‬‬ ‫وبالرغ���م م���ن تواج���د نظام للكش���ف عن‬ ‫الغ���از والحريق لم يتم منع مثل هذا الحادث‬ ‫الضخم وأثار هذا الحادث تساؤالت كثيرة عن‬

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‫ت���م تطويرها لتس���اعد المؤسس���ات على‬ ‫إس���تدامة نجاحه���ا التجاري مع أخ���ذ الحفاظ‬ ‫على البيئة بعين االعتبار‪.‬‬ ‫شهادة األيزو في مجال الجودة والسالمة‬ ‫والصحة المهنية ‪OHSAS 18001.2007‬‬ ‫يس���اعد المؤسس���ات على تطبي���ق جميع‬ ‫السياس���ات والضواب���ط واإلج���راءات الت���ي‬ ‫تحتاجها لضمان أفضل الممارسات في بيئة‬ ‫العمل بحيث تكون متوافق���ة مع المعايير‬ ‫الدولية‪.‬‬ ‫وتتوال���ى النجاحات بحصول الش���ركة على‬ ‫شهادة أيزو جديدة وهي‪:‬‬ ‫شـــهادة األيـــزو للســـالمة المرورية على‬ ‫ُ‬ ‫الط ُرق ‪:ISO 39001.2012‬‬ ‫وهي تطبيق معيار الس���المة المرورية على‬ ‫ُ‬ ‫الط ُرق وه���و معيار دول���ي أوروبي مصمم‬ ‫لمس���اعدة الش���ركات والهيئ���ات الت���ي لها‬ ‫مركبات لنقل األفراد أو النقل اللوجيس���تي‬ ‫وتمثل الش���هادة المعيار الش���امل لتطبيق‬ ‫أفض���ل الممارس���ات إلدارة مخاط���ر الط���رق‬ ‫والسالمة المرورية والحد من أخطار الحوادث‬ ‫المميتة واإلصابات الخطيرة‪.‬‬ ‫الهين وأن‬ ‫باألم���ر‬ ‫إن تحقي���ق النج���اح لي���س‬ ‫ِّ‬ ‫الحف���اظ عل���ى ه���ذا النج���اح ه���و التح���دي‬ ‫الحقيقي الذي يتطلب إتخاذ كافة جهود أبناء‬ ‫الش���ركة المخلصين وتعظيم قيم العمل‬ ‫المش���ترك والتع���اون‪ ،‬األمر ال���ذي يؤدي إلى‬ ‫تلبية احتياج���ات العمالء والوصول إلى الرضا‬ ‫الكامل للعمالء‪ .‬تلك اإلج���راءات وااللتزامات‬ ‫التي تحافظ على إس���تمرار وتجديد شهادات‬ ‫األيزو الحاصلة عليها الشركة ‪.‬‬ ‫هـــل لنـــا أن نتعـــرف على حجـــم أعمال‬ ‫الشركة وأرباحها خالل العام ‪2019‬؟‬ ‫• قامت الش���ركة بتقديم خدماتها إلى (‪)88‬‬ ‫ش���ركة من ش���ركات قطاع البترول (الهيئة‬ ‫– ‪ 3‬ش���ركات قابضة – ‪ 9‬شركات قطاع عام‬ ‫– ‪ 39‬ش���ركة قطاع مش���ترك – ‪ 33‬ش���ركة‬ ‫قط���اع اس���تثماري – ‪ 1‬أجنب���ي) باإلضافة إلى‬ ‫األفراد الخارجيين بإجمالي إيرادات لألنش���طة‬ ‫بلغ (‪ )2,937‬مليار جنيه عن عام ‪ 2018‬مقابل‬ ‫(‪ )2,022‬ملي���ار جني���ه ع���ام ‪2017‬م‪ ،‬وتتض���ح‬ ‫المؤشرات المالية لنصيب السهم من توزيع‬ ‫األرب���اح؛ حيث بلغت ‪ %100‬عن ع���ام ‪ 2018‬مقابل‬ ‫‪ %60‬ع���ن عام ‪ ،2017‬نس���بة العائد على حقوق‬ ‫الملكية بلغت ‪ %48,3‬عام ‪ 2018‬مقابل ‪%30,2‬‬ ‫ع���ام ‪ ،2017‬مع���دل دوران رأس المال العامل‬ ‫‪ 20‬مرة عام ‪ 2018‬مقاب���ل ‪ 19,3‬مرة عام ‪،2017‬‬ ‫المستثمر ‪ %14‬عام‬ ‫نسبة العائد على المال ُ‬ ‫‪ 2018‬مقابل ‪ %8,3‬عام ‪.2017‬‬ ‫كم عـــدد العاملين في إبســـكو وطرق‬ ‫رفع أدائهم المهنـــي واالرتقاء بالعنصر‬ ‫البشري؟‬ ‫• إجمال���ي ع���دد العمال���ة عل���ى مس���توى‬ ‫الش���ركة ‪ 1673‬عامل مقاب���ل ‪ 16845‬عامل‬ ‫لعام ‪ 2017‬وبيانهم كالتالي‪:‬‬ ‫‪ -1‬إجمالي عدد العاملين بالمركز الرئيسي ‪1135‬‬

‫عامل لعام ‪ 2018‬مقابل ‪ 1166‬عامل لعام ‪2017‬م‪.‬‬ ‫‪ -2‬إجمالي عدد العاملين بالمواقع الخارجية‬ ‫‪ 15568‬عام���ل لعام ‪ 2018‬مقابل ‪ 15679‬عامل‬ ‫لعام ‪2017‬م‪.‬‬ ‫قمنا بتحديث وإستكمال الهيكل الوظيفي‬ ‫وإعتماده من الجهات المختصة؛ ليتوافق مع‬ ‫النظرة المستقبلية للشركة‪.‬‬ ‫مـــاذا عـــن تطبيـــق سياســـات ومعاييـــر‬ ‫السالمة والصحة المهنية؟‬ ‫دائما إلى تطوير إبسكو وتحديث‬ ‫• نس���عى‬ ‫ً‬ ‫منظومة العمل ورفع األداء لتحقيق األهداف‬ ‫المرج���وة وخل���ق بيئة عمل آمن���ة خالية من‬ ‫الخس���ائر البش���رية والمادي���ة‪ ،‬وذل���ك ع���ن‬ ‫طري���ق تطوير وتحدي���ث منظوم���ة اإلطفاء‬ ‫ومكافحة الحريق بالش���ركة والحفاظ على‬ ‫الممتل���كات واألص���ول الخاصة بالش���ركة‪،‬‬ ‫وبناء عل���ى توجيهات معالي وزي���ر البترول‬ ‫والث���روة المعدنية الس���يد المهندس‪ /‬طارق‬ ‫المال بش���أن أهمية التنس���يق بين ش���ركات‬ ‫القط���اع الجغرافي الواحد ف���ي مجال األمن‬ ‫والس���المة والصحة المهني���ة وحماية البيئة‬ ‫وبالتع���اون الوثي���ق بي���ن الش���ركة العام���ة‬ ‫نظرا إلشراك إبسكو في‬ ‫للبترول وإبس���كو‬ ‫ً‬ ‫الموقع الجغرافي الواحد والتنس���يق الدائم‬ ‫في اإلستعدادات للطوارئ ومواجهة األزمات‪.‬‬ ‫هـــل تقـــوم الشـــركة بـــدور مجتمعي‬ ‫لخدمة المجتمع؟‬ ‫• ال تتوان����ى اإلدارة التنفيذي����ة بالش����ركة ع����ن‬ ‫تقديم ي����د العون وفق ما ترخ����ص به الجمعية‬ ‫العمومية للش����ركة ‪ ،‬حيث ساهمت إبسكو‬ ‫بالتب����رع للمراكز الطبي����ة للعاملين بالبترول‬ ‫خالل العام ‪ ، 2019‬باإلضافة للخدمات المجتمعية‬ ‫طبقًا للموقع الجغرافي للشركة‪.‬‬ ‫حدثنـــا عـــن الخطـــط التوســـعية‪ ،‬وهل‬ ‫الشـــركة بصـــدد إســـتحداث خدمـــات‬ ‫تقدمها لقطاع البترول؟‬ ‫‪ -‬منذ نشأة «إبسكو» من أكثر من عشرون‬

‫عام���ا تقري ًب���ا وه���ي ُمس���تمرة ف���ي تعزيز‬ ‫ً‬ ‫مواردها بنفس���ها للوفاء بالتزاماتها دون أي‬ ‫المتعاملة‬ ‫أعباء على القطاع أو الش���ركات ُ‬ ‫معها‪.‬‬ ‫ وإيمانًا من اإلدارة التنفيذية بالشركة بحجم‬‫الملقاة على كاهلها للحفاظ‬ ‫المس���ئولية ُ‬ ‫على إستمرار الشركة في تقديم خدماتها‬ ‫العدي���دة باعتبارها ش���ركة مصري���ة وطنية‬ ‫خالص���ة لتنمي���ة موارده���ا وتفعي���ل ما جاء‬ ‫من أنش���طة عديدة بالنظام األساس���ي لها‪،‬‬ ‫المساندة‬ ‫ً‬ ‫المتعلقة بالخدمات ُ‬ ‫خصوصا تلك ُ‬ ‫لعمليات البحث واالستكشاف‪ ،‬وكذا تقديم‬ ‫المس���اندة إلنتاج وتكرير‬ ‫الخدمات البترولية ُ‬ ‫َّ‬ ‫يتعلق بالتسويق وأعمال‬ ‫البترول وكافة ما‬ ‫الصيان���ة‪ ،‬وق���د ّ‬ ‫تجل���ى ذل���ك بالدخ���ول في‬ ‫أنش���طة جديدة لم تزاولها الشركة من قبل‬ ‫وذلك بالدخول في ش���راكات وتفاهمات مع‬ ‫الشركات الشقيقة والمتخصصة‪.‬‬ ‫‪ .a‬تنمية مهارات العاملين بالشركة وتقديم‬ ‫العروض وإعداد الدراسات المالية‪.‬‬ ‫‪ .b‬تنمية موارد الشركة وعدم اإلعتماد على‬ ‫أنشطة بعينها‪.‬‬ ‫ وال يفوتنا هنا إال أن نشير لما نلقاه من دعم‬‫ومس���اندة م���ن معالي الس���يد المهندس‪/‬‬ ‫وزير البترول والثروة المعدنية وكذا الس���يد‬ ‫المهن���دس‪ /‬الرئي���س التنفي���ذي للهيئ���ة‬ ‫ً‬ ‫وأيضا‬ ‫المصري���ة العامة للبت���رول ومعاونوه‬ ‫السادة الزمالء بش���ركات القطاع لإلستفادة‬ ‫المتاحة بش���ركات‬ ‫من كاف���ة اإلمكاني���ات ُ‬ ‫القطاع لتحقيق التكامل بينها‪ ،‬والتي ظهر‬ ‫أثرها جل ًيا على نتائج أعمال الشركة‪.‬‬ ‫وإذ نأم���ل زيادة حج���م األعمال خ���الل الفترة‬ ‫القادمة بإذن اهلل ‪،،‬‬

‫‪Petroleum Today - October 2019‬‬

‫‪9‬‬

‫فى حواره مع بتروليم توادى‬

‫المحاسب محمد مصطفى رئيس شركة إبسكو‪:‬‬

‫حصلنا على العديد من شهادات الجودة العالميــة‬ ‫ونقدم خدماتنا الكثر من ‪ 88‬شركة بإيرادات تبلغ‬ ‫نحو ثالثة مليارات جنيه‬

‫التعرف على تاريخ نشأة‬ ‫في البداية نريد‬ ‫ُّ‬ ‫الشركة والخدمات التي تقدمها لقطاع‬ ‫البترول وأبرز عمالئها؟‬ ‫• تأسس���ت الش���ركة المصري���ة للخدم���ات‬ ‫البترولية ( إبسكو) شركة مساهمة مصرية‬ ‫ً‬ ‫طبقا ألحكام القانون رقم (‪ )159‬لس���نة ‪1981‬‬ ‫الخاص بالش���ركات المساهمة في السجل‬ ‫التجاري بتاريخ ‪ 17‬ديسمبر ‪1997‬م‪.‬‬ ‫• تق���دم الخدم���ات والمع���دات واألجه���زة‬ ‫المس���اندة لعملي���ات اإلستكش���اف والحفر‬ ‫والصيانة واإلنتاج والتكرير والتسويق والنقل‬ ‫للم���واد البترولية مع توفي���ر العمالة الفنية‬ ‫وغير الفنية الالزمة لمنشآتها ومواقعها‪.‬‬ ‫الشـــركة حاصلـــة علـــى العديـــد مـــن‬ ‫شـــهادات الجودة العالميـــة‪ ،‬نود توضيح‬ ‫تلك الشهادات وكيف حصلت عليها وما‬ ‫أهميتها؟‬ ‫حصلت إبس���كو العام الماضي في أكتوبر‬ ‫‪ 2018‬على ‪ 4‬شهادات أيزو وهي‪:‬‬

‫‪8‬‬

‫‪Petroleum Today - October 2019‬‬

‫– ‪ISO 9001.2005 – ISO 22000.2005‬‬ ‫‪ISO 14001.2015 – OHSAS 18001.2007‬‬ ‫األمر الذي جاء بعد تنظيم الدورة المستندية‬ ‫بالش���ركة وكذلك اعتماد الوثائق والنماذج‬ ‫وتعديل الهي���اكل المنظم���ة لتتواكب مع‬ ‫التعدي���الت العالمي���ة الت���ي تعك���س حجم‬ ‫األعمال المسندة للشركة‪ ،‬وكذلك اإلتصال‬ ‫المس���تمرة بالعمال���ة الموجودة‬ ‫والتوعية ُ‬ ‫بالمواقع والتنسيق مع الشركات الشقيقة‬ ‫الملحقة عمالتنا بها من خالل العقد الموحد‬ ‫ُ‬ ‫لتقديم العمالة الفني���ة وغير الفنية لتوفير‬ ‫وس���ائل األم���ان‪ ،‬وكذل���ك الكش���ف عل���ى‬ ‫المخازن وضمان سالمة الغذاء وحماية البيئة‬ ‫والسالمة والصحة المهنية‪.‬‬ ‫شهادة األيزو في مجال الجودة الشاملة‬ ‫‪:ISO 9001.2015‬‬ ‫األي���زو ‪ 9001‬هي أحد ش���هادات المنظمة‬ ‫الدولي���ة للمقايي���س‪ ،‬وتتضم���ن ه���ذه‬ ‫الشهادة الدولية ما ينبغي عليه أن يكون‬ ‫نظام الجودة في الش���ركات التي يكون‬

‫مج���ال عمله���ا ف���ي اإلنت���اج أو الخدم���ات‬ ‫وتؤدي إلى ضمان إستمرارية وثبات جودة‬ ‫منتج���ات وخدم���ات المنش���آت وبالتالي‬ ‫إرض���اء عمالئه���ا‪ ،‬ورف���ع إنتم���اء العاملين‬ ‫وزيادة وعيهم تجاه الجودة‪،‬‬ ‫شـــهادة األيزو في مجال الجودة لسالمة‬ ‫الغذاء ‪:ISO 22000.2005‬‬ ‫وه���ي تعن���ي نظ���ام إدارة أم���ان الغ���ذاء‬ ‫تس���تخدم أيزو ‪ 22000‬من قبل أي مؤسس���ة‬ ‫ويدمج‬ ‫ضمن سلس���لة الس���المة الغذائي���ة‪ُ ،‬‬ ‫المعي���ار مب���ادئ نظ���ام تحلي���ل المخاطر‬ ‫ونقطة التحكم الحرجة (‪ )HACCP‬من خالل‬ ‫متطلبات قابلة للتدقيق والقياس‪.‬‬ ‫شهادة األيزو في مجال الجودة للسالمة‬ ‫البيئية ‪:ISO 14001.2015‬‬ ‫المواصف���ة الدولية أي���زو ‪ 14001‬هي المواصفة‬ ‫األش���هر عالم ًي���ا لنظ���ام اإلدارة البيئية‪ ،‬حيث‬ ‫تق���وم ه���ذه المواصف���ة بتحدي���د الطريقة‬ ‫فعالة وقد‬ ‫المثل���ى لوضع نظ���ام إدارة بيئية ّ‬ ‫ُ‬

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‫رؤية‬ ‫روؤي���ة‬

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‫للشــئون�ةاملاليــة‬ ‫الرشكــة‬ ‫األســتاذل‪/‬أ�شتاذ ‪ /‬هيثم‬ ‫الســيدال�شي ��د ا‬ ‫وكذلــكوكذلك‬ ‫لل�شئون املالي ��ة‬ ‫رئي�س ال�شرك �‬ ‫رئيــسع ��د‬ ‫مســاعد�ف م�شا‬ ‫يو�ش �‬ ‫ـم‬ ‫ـ‬ ‫العظي‬ ‫ـد‬ ‫ـ‬ ‫عب‬ ‫ـا‬ ‫ـ‬ ‫دالي‬ ‫‪/‬‬ ‫ـورة‬ ‫ـ‬ ‫والدكت‬ ‫‪،‬‬ ‫ـات‬ ‫ـ‬ ‫امله‬ ‫ـام‬ ‫ـ‬ ‫ع‬ ‫ـر‬ ‫ـ‬ ‫مدي‬ ‫ـم‬ ‫ـ‬ ‫اهي‬ ‫ر‬ ‫اب‬ ‫هيثــم‬ ‫ابراهي ��م مدي ��ر عام املهمات ‪ ،‬والدكت ��ورة ‪ /‬داليا عبد العظي ��م مدير عام توكيد‬ ‫مديــر عــام توكيــد الجــودة ‪ ،‬وقــد تــم عقــد عــدة إجتاعــات للمناقشــة‬ ‫اجل ��ودة ‪ ،‬وقد مت عقد ع ��دة اإجتماعات للمناق�شة و الإتفاق ح ��ول بناء روؤية عامة‬ ‫تواجــه كافــة منظــات األعــال يف عرصنــا الراهــن تحديــات كثــرة و اإلتفــاق حــول بنــاء رؤيــة عامــة وشــاملة تحمــل الصــورة و الحلــم‬ ‫ال�شرـكـة��ة م�شتقب ًا ‪،‬‬ ‫تكونإسـعليها‬ ‫ـتقباأاًم �‪�،‬ل اأن‬ ‫الذى ن‬ ‫ال�ش �‬ ‫نأم�ـ�ةـلحت‬ ‫و�شامل‬ ‫ـتغال كاف‬ ‫وكذلــك‬ ‫احللم مسـ‬ ‫�ورة والرشكــة‬ ‫عليهــا‬ ‫أنم �تك�لــون‬ ‫ي�شهده الــذى‬ ‫نتيجــة‬ ‫وحضاريــة‬ ‫صناعيــة‬ ‫تكنولوجيــا‬ ‫تواج ��هملــاكاف �يش�ةــهده‬ ‫كثرية مل ��ا‬ ‫حتديات‬ ‫الراه ��ن‬ ‫نهضـيفـة ع�شرنا‬ ‫ـاملاملـأعـنم ��ال‬ ‫منظم �العـ�ات‬ ‫التناف�شية لل�شركة‬ ‫القدرات‬ ‫لزيادة‬ ‫إمكانيات‬ ‫ل‬ ‫ا‬ ‫و‬ ‫الوا�شائل‬ ‫كافة‬ ‫إ�شتغال‬ ‫ا‬ ‫�ك‬ ‫�‬ ‫ل‬ ‫وكذ‬ ‫التطــورات العلميــة والتقنيــة الرسيعــة واملســتمرة‪ ،‬وأمــام تلــك الو ســائل و اإلمكانيــات لزيــادة القــدرات التنافســية للرشكــة وتطويــر‬ ‫الع ��امل من نه�شة تكنولوجيا �شناعية وح�شارية نتيجة التطورات العلمية‬ ‫ـوات االتيــة‬ ‫ـالمنالخطـ‬ ‫ـداف امـلـن خـ‬ ‫تلكاأله‬ ‫لتحقيقــة و‬ ‫أدائهاــك الرؤي‬ ‫لتحقيــق تل‬ ‫والتقنية أدائهــا‬ ‫التحديــات ونظ ـرا ً لوجــود إدارة فاعلــة داخــل رشكــة إبســكو حققــت‬ ‫اخلطوات‪-:‬التية ‪-:‬‬ ‫خال‬ ‫أهداف‬ ‫الرـوؤية و‬ ‫وتطوير ا‬ ‫األخــرةداخل‬ ‫إدارة فاعلة‬ ‫لوجود ا‬ ‫التحديات ونظر ًا‬ ‫وامل�شتمرة‪ ،‬واأمام‬ ‫ال�شريعة‬ ‫فقــد�شركة أوالً ًوضــع رؤيــة عامــة للرشكــة “ ان تصبــح إبســكو إحــدي الــرشكات‬ ‫الفــرة‬ ‫األصعــدة ىف‬ ‫تلكعــى كافــة‬ ‫النجاحــات‬ ‫الكثــر مــن‬ ‫الرائدة يف جمال‬ ‫اأول و�شع روؤية عامة لل�شركة “ ان ت�شبح اإب�شكو اإحدي ال�شركات‬ ‫عــى فقد الرائــدة يف مجــال تقديــم الخدمــات البروليــة عــي مســتوي مــرص‬ ‫اداريــاً‬ ‫منهجــاً‬ ‫تبنــت�تاإلدارة‬ ‫يعتمــدأخرية‬ ‫متقدمــاًالفرة ال‬ ‫أ�شعدة فى‬ ‫كافة ال‬ ‫بالرشكــة على‬ ‫العليــاالنجاحات‬ ‫الكثري من‬ ‫اإب�شكو حقق �‬ ‫�رق ‪.‬الأو�شط ب�شواعد اأبنائها‬ ‫�‬ ‫ش‬ ‫وال�‬ ‫م�شر‬ ‫م�شتوي‬ ‫علي‬ ‫البرولية‬ ‫�ات‬ ‫�‬ ‫م‬ ‫اخلد‬ ‫تقدمي‬ ‫وأحــدث النظــم ً العلميــة ىف اإلدارة مــن والــرشق األوســط بســواعد أبنائهــا بحلــول عــام ‪“ 2030‬‬ ‫األســاليب‬ ‫أفضــل‬ ‫إســتخدام‬ ‫تبن ��ت الإدارة العليا بال�شركة منهج ًا اداري ًا متقدم� �ا يعتمد على اإ�شتخدام ا‬ ‫‪. “ 2030‬‬ ‫وضععام‬ ‫ـدافأف�شل ثانياًبحلول‬ ‫العامة للرشكة ‪.‬‬ ‫األهداف‬ ‫خــال وضــع خطــة إسـراتيجية ‪ ، Strategic Plan‬وبنــاء رؤيــة وأهـ‬ ‫الأ�شالي ��ب واأح ��دث النظم العلمية فى الإدارة من خ ��ال و�شع خطة ا‬ ‫الرؤية واألهداف ‪.‬‬ ‫العامةلتحقيق‬ ‫أهدافالعمل‬ ‫عى خطة‬ ‫اإلتفاق‬ ‫لل�شركة ‪.‬‬ ‫و�شع ال‬ ‫إ�شراتيجية ثالثاًثاني ًا‬ ‫واضحــة ومحــددة للرشكــة اطلــق عليهــا رؤيــة إبســكو ‪ 2030‬إنســجاماً‬ ‫اطلقـععليها رابع ـاً‬ ‫ـال التحليــل‬ ‫للرشكؤيةــةوا ملــن خـ‬ ‫العملـع الحـ‬ ‫خطة للوضـ‬ ‫علىراســة‬ ‫إتفاقــل د‬ ‫ثالث ً‪:‬ا اتـلـم عم‬ ‫وتحديكـ��ة‬ ‫وحمددة لل�شر‬ ‫اتيجيةوا�شح �‬ ‫ـرول واأإسـه �ر�داف‬ ‫ـاع�اءالبرـوؤي ��ة‬ ‫‪، Strategic‬قطوبـن �‬ ‫ـث ورفـ‬ ‫واضحـ�ةـة لتطويــر‬ ‫‪ Plan‬مــع تبنــى‬ ‫أهداف ‪.‬‬ ‫ـاىلالرو‬ ‫لتحقيق‬ ‫كفــاءة أداء القطــاع ًانطاقــاً مــن مســئوليته ىف تنفيــذ رؤى اإلصــاح الرباعــي ‪. SWOT Analysis‬‬ ‫روؤية اإب�شكو ‪ 2030‬اإن�شجام� �ا مع تبنى قطاع البرول اإ�شراتيجية وا�شحة لتطوير رابع ًا ‪ :‬مت عمل درا�شة للو�شع احلاىل لل�شركة من خال التحليل الرباعي ‪SWOT‬‬ ‫اإلقتصــادى واإلجتاعــى الجاريــة ودوره كاعــب أســاىس ىف تنفيــذ رؤيــة خامساً‪ :‬القيام بتشكيل فرق عمل ‪.‬‬ ‫وحتدي ��ث ورفع كفاءة اأداء القطاع انطاق ًا من م�شئوليته فى تنفيذ روؤى الإ�شاح‬ ‫‪. Analysis‬‬ ‫القيام بتأهيل فريق عمل لضان تحقيق افضل النتائج ‪.‬‬ ‫‪ ، Egypt 2030‬وقــد تــم ذلــك مــن خــال فريــق عمــل برئاســة الســيد سادساً‪:‬‬ ‫تنفيذ رو‬ ‫االدارة ف ��ى‬ ‫ـسأ�شا�شى‬ ‫كاعب ا‬ ‫ودوره‬ ‫ـبلإجتما‬ ‫�ادىـوا‬ ‫عمل‬ ‫ـىفرق‬ ‫بت�شكيل‬ ‫ـات‪ Time .‬املحــددة لــكل ملــف عــى‬ ‫التوقيتـ‬ ‫القيامــاق عـ‬ ‫خام�ش ًات‪:‬ــم اإلتف‬ ‫‪ Egypt‬ســابعاً ‪:‬‬ ‫املنتـؤيةـدب‬ ‫والعضــو‬ ‫ـس مجلـ‬ ‫اجلارية رئيـ‬ ‫محمـع �ـد�ىمصطفــى‬ ‫الإقت�ش �املحاس‬ ‫م�شطفى حــدى ‪.‬‬ ‫حممد‬ ‫فريق عمل‬ ‫خال‬ ‫ذلكـمن‬ ‫‪ ، 2030‬وقد‬ ‫مســاعد‬ ‫املحا�شبـدرى‬ ‫ال�شيدمحمــد البـ‬ ‫برئا�شةــارق‬ ‫املحاســب ‪ /‬ط‬ ‫الســيد‬ ‫ـاعدية‬ ‫متـة مس‬ ‫ومعاونـ‬ ‫�شاد�ش ًا‪ :‬القيام بتاأهيل فريق عمل ل�شمان حتقيق اف�شل النتائج ‪.‬‬ ‫يوسـ‪/‬ـفطارق ثامناً ‪:‬‬ ‫ال�شيدمحمــد‬ ‫م�شاعديةـب ‪/‬‬ ‫ومعاونةـيد املحاسـ‬ ‫املنتدبــة ‪ ،‬السـ‬ ‫ـئون اإلداري‬ ‫الدارةـة للشـ‬ ‫جمل�س الرشكـ‬ ‫رئي�س رئيــس‬ ‫املحا�شب‬ ‫والع�شو‬ ‫‪. Feedback‬التوقيت ��ات ‪ Time‬املح ��ددة ل ��كل مل ��ف عل ��ى حدى ‪.‬‬ ‫النتائجف ��اق عل ��ى‬ ‫تقييم مت الإت‬ ‫�شابع� � ًا ‪:‬‬ ‫حممد البدرى م�شاعد رئي�س ال�شركة لل�شئون الإدارية ‪ ،‬ال�شيد املحا�شب ‪ /‬حممد ثامن ًا ‪ :‬تقييم النتائج ‪. Feedback‬‬ ‫ا‬

‫‪Petroleum Today - October 2019‬‬

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‫الرئي�س التنفيذي‪� :‬صل ما زالت متلك ال�صهية لال�صتثمار يف‬ ‫ال�صرق االأو�صط‬ ‫ق ��ال بن فان بي ��وردن الرئي�س التنفيذي لروي ��ال دات�س �شل اإن ال�شركة ل تعت ��زم تغيري خططها‬ ‫لا�شتثمار يف ال�شرق الأو�شط‪.‬‬ ‫واأبل ��غ بي ��وردن موؤمت ��ر النفط واملال قائ ��ا "ل نية لدينا عل ��ى الإطاق لتغيري موقفن ��ا و�شهيتنا‬ ‫لا�شتثمار يف ال�شرق الأو�شط‪ .‬نحن اأبعد ما نكون عن ذلك"‪.‬‬ ‫وان�شحب ��ت �شل من حقل جمنون النفطي يف العراق قب ��ل عامن وباعت يف وقت �شابق من العام‬ ‫اجلاري ح�شتها مب�شفاة يف ال�شعودية‪ .‬و�شل م�شتثمر كبري يف قطر و�شلطنة عمان‪.‬‬

‫الرئي�س التنفيذي‪ :‬الهجمات على اأرامكو ال�صعودية لي�س لها تاأثري على خطط الطرح‬ ‫قال الرئي�س التنفي ��ذي لأرامكو ال�شعودية اإنه لن‬ ‫يك ��ون هن ��اك اأي تاأثري على خط ��ط اإدراج عماق‬ ‫النفط اململوك للدولة بالبور�شة بعد هجمات على‬ ‫من�شاأتن تابعتن لها‪.‬‬ ‫وق ��ال اأمن النا�شر يف موؤمتر النفط واملال بلندن‬ ‫اإن هجمات مثل تل ��ك التي وقعت يف ‪� 1٤‬شبتمرب‪،‬‬ ‫والتي اأدت لرتفاع اأ�شعار النفط مبا ي�شل اإىل ‪20‬‬ ‫باملئ ��ة‪ ،‬قد ت�شتمر اإذا مل يكن هناك رد فعل دويل‬ ‫م�شرك‪.‬‬ ‫وا�شتهدف ��ت الهجم ��ات من�شاأتي بقي ��ق وخري�س‬ ‫وهما يف القلب من �شناعة النفط ال�شعودية‪ ،‬مما‬ ‫اأدى حلرائ ��ق واأ�شرار واأوق ��ف ‪ 5.7‬مليون برميل‬

‫يوميا من الإنت ��اج‪ ،‬وهو اأكرث من خم�شة باملئة من‬ ‫اإمدادات النفط العاملية‪.‬‬ ‫وق ��ال النا�ش ��ر يف ت�شريح ��ات �شيا�شي ��ة ن ��ادرة‬ ‫"غياب العزم الدويل لتخاذ اإجراء ملمو�س رمبا‬ ‫ي�شجع مهاجمن وبالفع ��ل يعر�س اأمن الطاقة يف‬ ‫العامل خلطر اأكرب‪.‬‬ ‫"�شمعت ��م وزير ال�ش� �وؤون اخلارجي ��ة واأعتقد اأنه‬ ‫حتدث مبا يكفي عن م ��ن (اأين) تاأتي الهجمات‪.‬‬ ‫اإنه ��ا بتحري�س من اإي ��ران بالطب ��ع‪ ..‬لي�س هناك‬ ‫�شك"‪.‬‬ ‫وحافظ ��ت ال�شعودية على الإم ��دادات للعماء عند‬ ‫امل�شتويات التي كانت عليها قبل الهجمات من خال‬

‫ال�شحب م ��ن خمزوناتها النفطية ال�شخمة وعر�س‬ ‫درجات خمتلفة من اخلام من حقول اأخرى‪.‬‬ ‫وقال النا�ش ��ر اإن الهجمات مل يك ��ن لها اأي تاأثري‬ ‫عل ��ى اإيرادات اأرامكو لأن ال�شركة وا�شلت التوريد‬ ‫للعم ��اء كم ��ا كان مق ��ررا‪ .‬وق ��ال اإن الهجم ��ات‬ ‫اأي�شا لي�س له ��ا اأي تاأثري على الطرح العام الأويل‬ ‫لل�شركة باأي �شكل من الأ�شكال‪.‬‬ ‫ومت�ش ��ي ال�شعودي ��ة قدم ��ا يف خطط لبي ��ع ما بن‬ ‫واح ��د باملئة واثن ��ن باملئة من اأرامك ��و من خال‬ ‫اإدراج حمل ��ي‪ ،‬وال ��ذي ق ��د يتبع ��ه مزيد م ��ن بيع‬ ‫الأ�شهم دوليا‪.‬‬

‫بي‪.‬بي تختار برنارد لوين رئي�صا‬ ‫تنفيذيا مقبال بعد تقاعد داديل‬ ‫العام القادم‬ ‫قال ��ت عماق النف ��ط الربيطاين بي‪.‬ب ��ي اإن رئي�س‬ ‫اأن�شطة املنب ��ع برنارد لوين �شيحل حمل بوب داديل‬ ‫يف من�ش ��ب الرئي�س التنفي ��ذي حن يتقاعد الأخري‬ ‫الع ��ام القادم بع ��د اأن ق�شى يف من�شب ��ه نحو ع�شر‬ ‫�شنوات‪.‬‬ ‫وان�شم لوين اإىل بي‪.‬ب ��ي يف ‪ 1991‬كمهند�س حفر‪،‬‬ ‫وت ��وىل من�شب رئي�س اأن�شطة تنقيب وتطوير واإنتاج‬ ‫النف ��ط والغ ��از للمجموع ��ة على م�شت ��وى العامل يف‬ ‫اأبريل ني�شان ‪.2016‬‬ ‫وقالت بي‪.‬ب ��ي اإن داديل‪ ،‬الذي ُعن رئي�شا تنفيذيا‬ ‫يف ‪ 2010‬بع ��د كارثة ديب ووت ��ر هواريزون يف خليج‬ ‫‪4‬‬

‫‪Petroleum Today - October 2019‬‬

‫املك�شيك‪� ،‬شيغادر من�شب ��ه بعد الإعان عن نتائج‬ ‫ال�شرك ��ة للعام بالكامل يف الرابع من فرباير �شباط‬ ‫من العام القادم‪.‬‬ ‫وق ��اد داديل ال�شركة ليعرب بها م ��ن حافة الإفا�س‬ ‫بع ��د اأن ت�شبب ��ت يف اأك ��رب ت�ش ��رب نفط ��ي يف تاريخ‬

‫الوليات املتحدة واجتاز بها انهيار اأ�شعار النفط‪.‬‬ ‫وق ��ال هلجه لون ��د رئي�س جمل� ��س اإدارة بي‪.‬بي يف‬ ‫بي ��ان "يف الوقت الذي حتدد فيه ال�شركة م�شارها‬ ‫ع ��رب التحول يف الطاقة فاإن ه ��ذا الوقت املنطقي‬ ‫حلدوث تغيري"‪.‬‬

‫اطالق اأول حوار ا�صرتاتيجى بني م�صر والواليات املتحدة االأمريكية فى جمال الطاقة‬ ‫اأطلقت م�ش ��ر والوليات املتحدة الأمريكية اأول حوار‬ ‫ا�شراتيج ��ي فى جمال الطاقة ب ��ن البلدين بح�شور‬ ‫املهند�س ط ��ارق املا وزير البرول وال ��رثوة املعدنية‬ ‫ودان برويليت نائب وزير الطاقة الأمريكى واملهند�س‬ ‫جاب ��ر الد�شوق ��ى رئي� ��س ال�شركة القاب�ش ��ة للكهرباء‬ ‫نائب� � ًا ع ��ن الدكت ��ور حمم ��د �شاك ��ر وزي ��ر الكهرباء‬ ‫والطاقة املتجددة‪.‬‬ ‫واأك ��د امل ��ا خ ��ال كلمت ��ه اأن العاق ��ات امل�شري ��ة‬ ‫الأمريكي ��ة ممت ��دة تاريخي� � ًا والتع ��اون امل�شرك بن‬ ‫البلدين م�شتمر من ��ذ عقود واأن احلوار ال�شراتيجى‬ ‫يه ��دف اإىل دع ��م مزي ��د م ��ن التع ��اون ف ��ى جم ��ال‬ ‫الطاق ��ة ويعد فر�شة لتب ��ادل وجهات النظ ��ر والآراء‬ ‫حول الفر� ��س ال�شتثمارية املتاحة ف ��ى قطاع الطاقة‬ ‫بال�شاف ��ة اإىل دع ��م الرواب ��ط التجاري ��ة وزي ��ادة‬ ‫ال�شتثم ��ارات الأجنبي ��ة املبا�شرة ف�ش� � ًا عن �شمان‬ ‫ا�شتمرار حتقيق النجاحات فى جمال الطاقة‬ ‫وم ��ن جانب ��ه اأكد نائ ��ب وزي ��ر الطاق ��ة الأمريكى اأن‬

‫تنفيذ م�صروعات لتطوير املنظومة‬ ‫االإنتاجية مبناطق امتياز عجيبة‬ ‫جنحت �شركة عجيبة للبرول يف رفع متو�شط اإنتاجها‬ ‫م ��ن الزيت اخلام لي�ش ��ل اإىل ح ��واىل ‪ ٤٤‬األف برميل‬ ‫يومي ًا وحواىل ‪٤‬ر‪ 18‬مليون قدم مكعب غاز يومي ًا‪.‬‬ ‫واأو�ش ��ح تقري ��ر نتائج اأعم ��ال �شركة عجيب ��ة للبرول‬ ‫للعام املاىل ‪ 2019/2018‬الذى قدمه املهند�س ع�شام‬ ‫القفا� ��س رئي�س ال�شرك ��ة للمهند�س ط ��ارق املا وزير‬ ‫الب ��رول الرثوة املعدنية اأن زيادة الإنتاج جاءت نتيجة‬ ‫لب ��دء اإنت ��اج حقل جنوب غ ��رب مليح ��ة يف �شهر يونيه‬ ‫املا�شى مبتو�شط اإنتاج األفي برميل زيت خام يومي ًا من‬ ‫البئر الأول ثم ارتفع الإنتاج اإىل ‪ ٤500‬برميل زيت خام‬ ‫يومي ًا بعد و�شع البئر الثانى على الإنتاج ‪ ،‬ومن املتوقع‬ ‫اأن ت�شل الطاقة الإنتاجية الق�شوى للحقل اإىل ‪ 7‬اآلف‬ ‫برميل زيت خام يومي ًا خال الفرة القادمة فور و�شع‬ ‫البئ ��ر الثالثة على الإنت ��اج ‪ ،‬كما متكن ��ت ال�شركة من‬ ‫اإ�شافة حواىل األفي برميل يومي ًا على الإنتاج من حقل‬ ‫اأ�شرف ��ى بخلي ��ج ال�شوي�س لي�شل اإنتاج ��ه اإىل حواىل ‪٤‬‬ ‫اآلف برمي ��ل زيت خ ��ام يومي ًا ‪ ،‬فيم ��ا اأ�شافت اأن�شطة‬ ‫احلفر بحق ��ل فر�س مبنطقة امتياز مليحة بال�شحراء‬ ‫الغربية متو�شط األفي برميل زيت خام يومي ًا من خال‬ ‫حفر ‪ 8‬اآبار تنموية و�شيانة الآبار القائمة لي�شل اإنتاج‬ ‫احلقل اإىل ‪ ٤100‬برميل زيت خام يومي ًا‪.‬‬

‫احل ��وار ال�شراتيج ��ى �شي�شه ��ل التع ��اون الوثيق بن‬ ‫احلكوم ��ة والقط ��اع اخلا�س ف ��ى جم ��ال الطاقة بن‬ ‫الوليات املتحدة وم�شر و�شريكز على تطوير جمالت‬ ‫العم ��ل فى قط ��اع البرول والغ ��از وعل ��ى التعاون فى‬ ‫املجالت الفنية للكهرباء والطاقة ‪ ،‬م�شري ًا اأن اطاق‬ ‫احلوار بداأ من خ ��ال الجتماعات التي متت موؤخر ًا‬ ‫ب ��ن الرئي�س ال�شي�شى والرئي�س دونالد ترامب وهو ما‬ ‫دعمه ريك بريى وزير الطاقة الأمريكى خال زيارته‬ ‫الأخرية مل�شر‪ ،‬واأ�شاف برويليت اأن الوليات املتحدة‬ ‫�شتتعاون مع م�شر من خال هذا احلوار فى عدد من‬

‫املج ��الت ذات الهتم ��ام امل�شرك ق ��ى قطاع الطاقة‬ ‫خا�شة فى جم ��الت تعزيز جتارة الطاقة وتكنولوجيا‬ ‫الفح ��م النظي ��ف وا�شتخ ��دام الكرب ��ون وتخزين ��ه‬ ‫والقت�شاد احليوى وكفاءة الطاقة والطاقة املتجددة‬ ‫وتقنيات املبان ��ى اخل�شراء وال�شب ��كات الذكية وبناء‬ ‫ق ��درات الطاقة وغريها‪ ،‬لفت ًا اأن احلوار يوؤكد الدعم‬ ‫الأمريك ��ى امل�شتم ��ر ملنتدى غاز �ش ��رق املتو�شط ودور‬ ‫م�شر كمركز طاقة اقليمى للغاز الطبيعى والكهرباء‬ ‫‪ ،‬واأك ��د اأن احلكوم ��ة والقط ��اع اخلا� ��س الأمريكين‬ ‫عل ��ى اأمت ا�شتعداد للتعاون مع م�شر لتعزيز اأمنها فى‬ ‫جمال الطاقة واأمن املنطقة‪.‬‬ ‫وفى ختام الجتم ��اع مت التفاق على ت�شكيل جمموعة‬ ‫عمل لتفعي ��ل بنود مذكرة التفاه ��م يف جمال الطاقة‬ ‫والتي مت توقيعه ��ا بالقاهرة يف يوليو املا�شى مع وزير‬ ‫الطاقة الأمريك ��ي لتحديد اأولويات العمل والتوقيتات‬ ‫الازم ��ة لتنفي ��ذ جم ��الت التع ��اون وامل�شروع ��ات‬ ‫امل�شتهدف العمل عليها وجذب ال�شتثمارات ‪.‬‬

‫م�ص��ر تخط��ط لرفع انت��اج الزي��ت اخل��ام اىل ‪ 700‬الف برمي��ل يومي ًا‬

‫اأك ��د املهند� ��س ط ��ارق املا وزي ��ر الب ��رول اأهمية‬ ‫زيادة القدرات الإنتاجية احلالية من الزيت اخلام‬ ‫وتنفي ��ذ اخلط ��ط والربام ��ج املو�شوع ��ة لتنعك� ��س‬ ‫ايجاب� � ًا على القت�شاد امل�شرى ‪ ،‬لفت ًا اىل ان خطة‬ ‫الوزارة ت�شته ��دف الو�شول مبع ��دلت اإنتاج الزيت‬ ‫اخل ��ام واملتكثف ��ات خال العام امل ��اىل احلايل اىل‬ ‫حواىل ‪ 700‬الف برميل يومي ًا ‪.‬‬ ‫جاء ذل ��ك خال زيارته حلقل اإنتاج بدر ‪ 3‬مبنطقة‬ ‫ال�شح ��راء الغربي ��ة اجتم ��اع حي ��ث عق ��د اجتماع‬ ‫عم ��ل مو�شع م ��ع روؤ�شاء ال�ش ��ركات الأعل ��ى اإنتاج ًا‬ ‫للزي ��ت اخلام بقط ��اع البرول والذى �ش ��م روؤ�شاء‬

‫�شركات بروبل وخالدة وقارون وبدرالدين وعجيبة‬ ‫وجابك ��و‪ ،‬وذل ��ك ملتابعة تنفيذ خط ��ط اإنتاج الزيت‬ ‫اخلام خ ��ال العام امل ��اىل احل ��ايل ‪2020/2019‬‬ ‫ومراجع ��ة وتقيي ��م الأداء النتاج ��ى لل�ش ��ركات‬ ‫والوقوف عل ��ى تطورات العم ��ل والتعرف عن قرب‬ ‫على مايواجهها من حتديات ‪.‬‬ ‫وقد مت خال الجتم ��اع ا�شتعرا�س خطط �شركات‬ ‫الإنت ��اج ال�ش ��ت م ��ن جان ��ب روؤ�ش ��اء ال�ش ��ركات ‪،‬‬ ‫وبرنامج العمل خال الأ�شه ��ر الت�شعة القادمة من‬ ‫العام امل ��اىل ‪ 2020/2019‬لتحقيق اهداف اخلطة‬ ‫والآلي ��ات الت ��ي مت اعتماده ��ا للتنفي ��ذ ف�ش ��ا عن‬ ‫ا�شتعرا�س التحديات الرئي�شية واحللول ملواجهتها‪.‬‬ ‫‪Petroleum Today - October 2019‬‬

‫‪3‬‬

‫األخبـــار‬ ‫البرتول توقع ‪ 4‬اتفاقيات تعاون مع �صركات البرتول العاملية العاملة فى م�صر‬ ‫�شه ��د املهند� ��س طارق امل ��ا وزير الب ��رول والرثوة‬ ‫املعدنية توقيع ‪ ٤‬اتفاقيات تعاون مع عدد من �شركات‬ ‫الب ��رول العاملي ��ة العاملة يف م�ش ��ر وت�شمل �شركات‬ ‫اأبات�ش ��ى وبى بى واإينى وكوي ��ت انرجى ايوك‪ ،‬وذلك‬ ‫لتدري ��ب ك ��وادر الإدارة ال�شاب ��ة واملتو�شط ��ة �شم ��ن‬ ‫برنامج م�شروع تطوير وحتديث قطاع البرول‪.‬‬ ‫واأك ��د امل ��ا اأن م�ش ��روع تطوي ��ر وحتدي ��ث القطاع‬ ‫ي�شته ��دف ال�شتثمار يف الك ��وادر الب�شرية و العقول‬ ‫ال�شاب ��ة املتمي ��زة ‪ ،‬ويعم ��ل عل ��ى حتقي ��ق ذلك من‬

‫خ ��ال برامج تدري ��ب متكاملة ومواكب ��ة للتطورات‬ ‫التكنولوجي ��ة يف �شناع ��ة الب ��رول لفت� � ًا اأن ه ��ذه‬ ‫الربام ��ج تتبن ��ى ا�شالي ��ب غري منطي ��ة يف التدريب‬ ‫والتاأهيل تواكب م�شتحدثات ال�شناعة البرولية‪.‬‬ ‫ووفق ��ا له ��ذه التفاقي ��ات ف�شيت ��م تدري ��ب وتاأهي ��ل‬ ‫املجموع ��ات املتمي ��زة م ��ن عنا�ش ��ر الدارة ال�شاب ��ة‬ ‫واملتو�شطة التي اجتازت الختبارات املكثفة لالتحاق‬ ‫بربنامج مت ت�شميمه واعداده لتاأهيلهم للقيادة وتقوم‬ ‫ال�ش ��ركات العاملي ��ة بتنفيذ برامج التدري ��ب والتاأهيل‬

‫له ��م يف مواق ��ع العم ��ل التابع ��ة له ��م وفق� � ًا لأح ��دث‬ ‫الأ�شالي ��ب العلمي ��ة والعملية وذلك �شم ��ن الربنامج‬ ‫الثالث مب�شروع تطوير وحتديث قطاع البرول ‪.‬‬ ‫وق ��ع التفاقيات الأرب ��ع اأ�شامة مب ��ارز وكيل وزارة‬ ‫البرول للمكتب الفنى مع كل من ديفيد ت�شى رئي�س‬ ‫�شرك ��ة اأبات�شي م�شر واملهند� ��س كرمي عاء رئي�س‬ ‫�شرك ��ة بى بى م�شر وفابيو كافانا مدير عام �شركة‬ ‫اأي ��وك الدولية وكامل ال�ش ��اوى رئي�س �شركة كويت‬ ‫انرجى مب�شر‬

‫�صركتى ر�صيد والربل�س ‪ :‬االنتهاء من حفر كافة اآبار املرحلة ‪( 9‬ب) وبدء االعداد للمرحلة العا�صرة‬ ‫اأو�شح ��ت نتائ ��ج اأعم ��ال ع ��ام ‪2019/2018‬‬ ‫ل�شركتى ر�شيد والربل�س والتى قدمها املهند�س‬ ‫�شربى ال�شرقاوى رئي�س ال�شركة اإىل املهند�س‬ ‫ط ��ارق امل ��ا وزي ��ر الب ��رول وال ��رثوة املعدنية‬ ‫جن ��اح ال�شركة يف النتهاء م ��ن حفر باقى اآبار‬ ‫م�ش ��روع تنمي ��ة واإنت ��اج املرحل ��ة ‪(9‬ب) باملياه‬ ‫العميق ��ة بغرب الدلتا وجارى حالي ًا العمل على‬ ‫ربطها عل ��ى الإنت ��اج تباع ًا لإ�شاف ��ة نحو ‪390‬‬ ‫مليون قدم مكعب غاز يومي ًا من اإجماىل ‪ 6‬اآبار‬ ‫‪ ،‬ومن املتوقع النتهاء م ��ن و�شع الآبار الثاث‬ ‫الأوىل عل ��ى الإنت ��اج يف الرب ��ع الأخري من عام‬ ‫‪ 2019‬مبع ��دل انت ��اج ح ��واىل ‪ 220‬مليون قدم‬ ‫مكعب غاز يومي ًا‪.‬‬ ‫‪2‬‬

‫‪Petroleum Today - October 2019‬‬

‫وت�شم ��ل خط ��ة عم ��ل ال�شركة ‪ 3‬حم ��اور ق�شرية‬ ‫ومتو�شط ��ة وطويل ��ة امل ��دى ‪ ،‬واأ�شف ��ر برنام ��ج‬ ‫العم ��ل ق�ش ��ري املدى ع ��ن جناح جه ��ود ال�شركة‬ ‫يف تعظي ��م ال�شتفادة م ��ن التكنولوجيا املتقدمة‬ ‫خ ��ال عملي ��ات حف ��ر الآب ��ار باملرحل ��ة ‪(9‬ب)‬ ‫وا�شته ��داف طبق ��ات ا�شتك�شافي ��ة عميقة بتكلفة‬ ‫ا�شتثمارية منخف�شة ع ��ن اكت�شاف طبقة حاملة‬ ‫للغازات من البئر "�ش ��وان �شرق" والتي اأ�شافت‬ ‫حواىل ‪ 67‬ملي ��ار قدم مكعب من املخزون القابل‬ ‫لا�شتخ ��راج ‪ ،‬وعلى املدى املتو�شط يجرى حالي ًا‬ ‫عق ��د ور�س عم ��ل واجتماعات فنية م ��ع ال�شركاء‬ ‫الأجان ��ب لتحدي ��د اأف�ش ��ل الفر� ��س التنموي ��ة‬ ‫للمرحل ��ة العا�ش ��رة م ��ن احلق ��ل حي ��ث اأ�شفرت‬

‫الدرا�ش ��ات عن اختي ��ار اأف�شل ‪ 7‬اآب ��ار تنموية‬ ‫ويت ��م حالي ًا تقيي ��م باق ��ى الآبار لزي ��ادة عدد‬ ‫الآب ��ار امل�شتهدفة من هذه املرحلة ‪ ،‬وت�شتهدف‬ ‫ال�شرك ��ة على امل ��دى البعيد الو�ش ��ول لطبقات‬ ‫عالي ��ة ال�شغط واحل ��رارة ومت اجراء عدد من‬ ‫الدرا�شات ال�شيزمي ��ة اأ�شفرت عن و�شع خطة‬ ‫حلف ��ر ‪ ٤‬اآب ��ار ا�شتك�شافي ��ة باأ�شالي ��ب علمي ��ة‬ ‫متقدمة لبل ��وغ الطبقات العميقة وجارى حالي ًا‬ ‫حف ��ر اأوىل الآب ��ار ال�شتك�شافية وال ��ذى يتمتع‬ ‫باحتمالت واعدة على عمق ‪ 20‬األف قدم حتت‬ ‫�شطح البحر بتكلفة ‪ 58‬مليون دولر‬