All articles in the Paid Post Section:


EUNISELL CREATES NEW BUSINESS MODEL FOR OIL COMPANIES, OVERCOMES DEVELOPMENT FINANCE BARRIERS FOR NOCs

PARTNER CONTENT

Eunisell Production Solutions has pioneered a new business model, enabling NOCs to realise their development goals and bring their fields up to optimum operating potential, without relying on external investment. 

The delay between when the blocks are awarded and when development commences, is a tangible concern for any investor or financial institution. Obstacles to the execution of development plans for these assets has indicated an insecurity of when a return on investment might be achieved, thus uncertainty and reluctance are created.

To solve the challenge, Eunisell delivers four key business benefits: 1. Faster delivery of first oil revenues. 2. Enhanced production from proven fields. 3. Engineered solutions for long term development and 4, Innovative technology.

NOCs are already reeling from the impact of Covid-19 on the industry and depressed oil prices. This means that owners will continue struggle to finance the development of their fields. Any financial assistance in that scenario would be limited at best and come at a heavy cost.

Added pressure comes from Government where owners are expected to deliver on the agreed development and output or risk losing their concessions as witnessed in recent times with the cancellation of 11 operators’ licenses. With the economic and global status quo, options are limited, if any, and this is why Eunisell has stepped in. Eunisell has been providing services based on experience, technology, economics and now, business innovation, to assist NOCs to develop their fields profitably over a measured period.

Service companies are able to design and deliver EPCC projects that will provide long term production and income for the NOCs. The problem is that these projects are inherently costly and require large payments at numerous milestones before production is actually achieved. The procurement and construction phases of these projects are extremely capital intensive and protracted.

By providing solutions, there is a positive impact on Nigeria’s GDP in addition. More oil yielded by NOCs translates into additional national revenues. Having large potential reserves not being produced, simply because a way cannot be found to bring the needed investment, facilities and technology to operators, is a negative influence on our industry, and Nigeria’s economy.

Each one of these assets or the assets currently included in the Marginal Field Bid Round that can be brought to production and developed to its full potential, represents significant increments to foreign exchange and taxes for government. Furthermore, there’s increased employment, community development and growth for the local economies.

The positive effect of bringing these fields to potential is enormous for all levels of the economy. Eunisell is in effect, acting as a technical partner, engineering and delivering the means to bring the existing production to market rapidly, generating revenue and enabling further development.

Compared to existing EPCC projects, Eunisell’s solution requires only a relatively minimal initial cost and is delivered in weeks rather than months. This immediate approach enables concurrent development of the asset. Eunisell will design and deliver the fit-for-purpose production management project, leaving operators to concentrate on long-term production expansion plans.

By working with the field owner, Eunisell assures that the solution provided serves not only short-term output yields, but is designed to meet the field’s expected potential and beyond. By providing the technical solutions and funding the development through rapid delivery of production, the capital required for field development is reduced to manageable levels. Further, the return on the original capital investment is achieved in a significantly shorter period of time.

With Eunisell’s model for success, we are using production costs to partner with the operators to develop the asset. And with Eunisell’s production enhancement and production delivery capacities, these costs can be further reduced to make depressed oil prices viable and enable funding development of Nigerian assets for the benefit of all.

Eunisell Production Solutions

www.eunisellproduction.com

info@eunisell.com

+234 908 765 9938

 


Welltec Solves Geothermal Problems with Oil Industry Technology

Welltec, the Denmark headquartered oil service provider, says that the cleaning tools it manufactures have proven highly successful during testing for something other than oil wells: geothermal well cleaning applications.

The Well Miller® has capabilities for:
–          Silica removal – a common cause of geothermal production issues
–          Rigless intervention
–          Minimal footprint – lightweight yet high capacity tools
–          Saving time and money through fast

The Well Miller Reverse Circulating Bit (RCB) is a combinable milling tool enabling the simultaneous milling, break-up, and extraction of scale. The RCB also features a turbine section allowing well fluid to be circulated through the milling bit, and for any cuttings or debris to be collected into bailer chambers for later recovery once tools are rigged down at surface.

In testing, the RCB was run against a cured blend of silica pieces (Si02), sand, and epoxy resin, to replicate the most challenging silica clean-out scenario found in a geothermal setting.

“Not only was the removal of the silica replicant compound successful, the mill bit showed almost no signs of wear, thanks to highly resistant Tungsten Carbide milling teeth”, Welltec reports I a case study.

Overcoming Challenges

Welltec says it is already helping clients with geothermal well construction by providing the Welltec Annular Barrier (WAB®) for zonal isolation – a life of well solution.

“In terms of maintenance and intervention, Silica scale is one of the main flow production issues found in Geothermal wells.  In particular, the challenge faced with this type of material stems from its strength and high level of resistance, making it incredibly difficult to mill through”, the company explains.

Geothermal Potential

Welltec believes that Geothermal energy offers the highest capacity energy form within the renewables market.  ”With the ongoing development of Enhanced  Geothermal Systems (EGS), the future potential is further expanded and can help to facilitate an even more efficient and sustainable way to harness the Earth’s natural energy source,” the company declares on its website.

Collaboration in the Field

Welltec continues to collaborate with industry experts and provide technology for research projects with allocated funding from the U.S. Department of Energy. In a project led by the University of Oklahoma and Veizades & Associates, Welltec will be testing its latest Welltec Annular Barrier (WAB) in multiple zones of interest at the Coso Geothermal Field, California.The WAB will be applied to achieve zonal isolation and improve mass flow through stimulation in a high temperature environment.

Academic contribution

Welltec has recently co-authored an academic paper with Energy Development Corporation (EDC) of the Philippines, presenting highly successful well repair operations from the field. The paper highlights the benefits of repairing wells to re-establish production rather than abandoning them for new ones– in doing so, the WAB can prevent casing collapse and deformation caused by trapped water.

The case will be presented at the 42nd New Zealand Geothermal Workshop on 24-26 November, 2020.


Danite Limited: Making E&P Field Development Affordable

PARTNER CONTENT

As multinational oil and gas companies (the IOCs) divest their interests in mostly onshore ventures in the Gulf of Guinea, new local E&P companies emerge, taking advantage of the divested interests. In many cases these new local ventures underestimate the challenge of maintaining production at inherited levels, and of developing and pursuing growth plans. Danite Limited recognises these challenges and seeks to support these private firms in a cost-effective way. We see the key challenges as follows:

Executive Steering:

Entrepreneurs that are new to the E&P sector often struggle with the time frame for making returns on their investment. An investor in the downstream oil and gas sector is basically a trader. The most critical success factors in that sector are: (a) A safe and efficient supply and distribution system that keeps costs really low (in view of the razor-thin profit margins), and (b) Attractive retail outlets which consumers would want to patronise. If the investor gets these things right in the downstream, he should be fine.

However, the upstream is a totally different ball game. The most critical success factors are (a) Technology, and (b) Safety and Environment. Drilling a couple of dry wells can sink the business. A few years ago, one multinational company drilled two dry wells offshore Nigeria at a total cost of almost US$200m and that was the end of its venture in the country. On safety and the environment, we have read of some of the world’s worst disasters in the Gulf of Mexico and how respected multinational companies have paid very dearly in both human lives, money and reputation.

Danite Limited seeks to support new investors into the industry by helping them understand the investment journey so they can manage their expectations, and by giving them sound steers as they embark on their first field developments. Sometimes, if they so request, we can provide a project manager who would work with the client’s resources to deliver successful projects.

Resourcing:

There is the immediate challenge of technical resourcing due to the dearth of capable technical manpower in the country. The newcomers typically seek to attract experienced technical resources from the IOCs. They soon find out that these technical experts sometimes with decades of experience would not easily leave their current employers with all the stability associated with IOCs, to join newcomers where a lot more is required of them, and with all the uncertainty of what lies ahead. Despite this challenge, with enough carrots, the newcomers do manage to attract some experienced technical resources. Often, these are resources that are close to normal retirement from the multinationals and so have little to lose by retiring early. But the future of the business cannot hinge on senior retired professionals – the newcomers need to invest in some inexperienced resources – typically graduates of technical disciplines – who can be developed very rapidly to be productive. Danite Limited offers to help develop such rookies through training programmes offered by industry veterans. Within a few weeks of employment, young graduates would be able to deliver real useable work that add value.

Affordable Software Tools:

There are well-known big names in the industry when it comes to software tools. For example, when you talk of process simulation, Aspen’s HYSIS is the industry standard. For pipeline studies, you speak of PipeSim – a Schlumberger product. These products have deservedly made their name from the patronage of the industry heavyweight operators. This has fuelled astronomical prices of these products, often beyond affordability of a new entrant into the business. However, from a technical standpoint, these software tools are based on well-known engineering principles, formulae and correlations, and their functionality can be replicated by much more affordable alternatives. This is the concept Danite Limited promotes – Provide useable tools without the mega-prices of the big names. For example, Danite’s RaffloLive (https://rafflolive.com) is a perfect solution for carrying out flow assurance studies of pipelines such as are encountered in the oil and gas fields. RaffloLive is the online version of what used to be a PC-based software called Rafflo, developed in the eighties by the current CEO of Danite Limited. After rigorous testing and validation, Rafflo was adopted by one of the leading IOCs in Nigeria as the official tool for pipeline flow assurance studies. That IOC used Rafflo for 13 years until the company received a directive from its headquarters to only use global industry software. Retaining the core Rafflo engine, Danite has re-created it into RaffloLive – a full on-line application that only requires a web browser to run. It does not require anything to be installed on the user’s device as everything is online. Even an Android tab or an iPad can be used to simulate huge pipeline networks with RaffloLive. It is offered by subscription only. However, participants at our training course on Pipeline Planning and Design automatically receive a 30-day license that enables them carry out hands-on exercises.

Field Development Planning:

The seeds of failure of many failed E&P projects are sown at the development planning stage. At this stage, you need your most experienced professionals who, working as an integrated team of surface and subsurface professionals, with other supporting disciplines like Safety, Environment and Corporate Social Responsibility (CSR), would develop optimal concepts. Danite Limited offers this service.

The CEO:

Dr Raphael Sunday Awoseyin founded Danite Limited. He has four decades experience in the upstream and downstream sectors of the petroleum industry, covering project management, facilities engineering, maintenance and management of oil and gas production facilities, processing and distribution, process re-engineering and business process integration. He has led formulation of standards, business processes and procedures for upstart E&P companies and championed skills and career development planning for thousands of operations 

personnel. He led implementation of SAP (ERP system) for the largest Shell E&P company in the world.

He holds a First-Class BSc (Hons) degree in Mechanical Engineering from University of Greenwich, London and a PhD, also in Mechanical Engineering, specialising in Pipeline Hydraulics. He is a graduate of IMD (Lausanne) Program for Executive Development and of Wharton (University of Pennsylvania) Executive Development Program. He is a Master of Business Process Re-engineering.


Foot on the Gas – Developers of Matola LNG terminal intensify talks with potential customers to reach 2023 supply date

PAID POST

The front-end engineering design phase for a proposed greenfield liquefied natural gas (LNG) import terminal at the Port of Matola, in the Mozambican capital of Maputo, is underway and the developers of the project are now intensifying discussions with potential energy and industrial off-takers in both Mozambique and South Africa.

The project is being developed by the Beluluane Gas Company (BGC), a joint venture between French energy multinational Total and Southern African natural gas group Gigajoule. Mozambique’s State-owned gas company, ENH, also has a share in the project, which is currently scheduled to begin operating in 2023.

In 2019, Mozambique awarded an LNG import concession to BGC and approved the construction of a 16-km, 28-inch pipeline linking the terminal to the existing Matola Gas Company (MGC) transmission network.

The Mozambican market consumes about 30 petajoules (PJ) per year of natural gas to gas-to-power and industrial off-takers. The vast majority is supplied through the MGC network which is also connected to the 865-km Rompco pipeline that currently transports some 150 PJ a year of natural gas to industrial customers in South Africa, including Sasol’s fuels and chemicals facilities in Secunda and Sasolburg.

The gas transported to South Africa is produced at Sasol’s Pande and Temane gas fields, in southern Mozambique.

Supply Squeeze

The development of the LNG terminal is being timed, however, to fill a supply gap that is anticipated to arise when production from those gas fields begins to taper from 2023 onwards. Ahead of the Covid-19 pandemic, the Industrial Gas Users Association of Southern Africa was forecasting a potential yearly gas shortfall in South Africa of up to 98 PJ from 2025 onwards.

The Rompco pipeline has a nameplate capacity of 220 PJ and Gigajoule Managing Director Johan de Vos and Total LNG business development director Shammi Herai report that the Matola terminal is being profiled to eventually match Rompco’s full capacity.

“Initially, we expected that most of the customers would be in South Africa, but we are receiving strong interest in Mozambique, which could shift the terminal’s supply equation materially,” De Vos says.

Besides servicing gas-to-power and industrial customers that are already linked to the gas network, the project includes scope for a cryogenic facility able to load trucks with LNG destined for customers that have no direct access to the existing pipeline infrastructure. “This is a very exciting market segment and we are contemplating a sculpted design that enables us to supply this market with more than 20 PJ of gas yearly as from 2023 onwards.”

Complementing Renewables

Herai, meanwhile, is equally enthused by the prospect of deploying the gas in support of the region’s push to increase the penetration of variable renewable energy into the electricity mix. BGC is also keeping close tabs on Eskom’s plans for the repurposing of four coal-fired power stations in the Mpumalanga province, which could include a gas-to-power component.

In addition, Central Térmica de Beluluane (CTB) secured a concession in 2019 for a 2 GW power plant project in Beluluane Industrial park, which will be supplied by BGC.

“Multiple discussions with interested parties are already under way despite the restrictions imposed by Covid-19 lockdowns, and the project is still on
course to reach final investment decision (FID) in the first half of 2021,” Herai explains.

BGC, De Vos highlights, needs the market to supply information with regards to industrial energy requirements as well as on-site power demand to enable it to progress to an FID as soon as possible and also to improve prospects for the supply of competitively priced natural gas.

“Infrastructure is a fixed component so it is in the interest of all customers that BGC aggregates sufficient volume to have significant economies of scale. The price to each customer will cover the molecule price and infrastructure costs, which means that all customers benefit from higher volumes.”

The process of securing commitments from customers is continuing in parallel with the front-end engineering design, which has been initiated after the BGC technical team resolved the critical technical and environmental issues confronting the project.

Project Progress

The front-end engineering design studies, meanwhile, are being advanced following the signing, in November, of a joint development agreement between Total and Gigajoule. Once completed, BGC will go out on enquiry to secure the services of an engineering, procurement and construction partner.

BGC will install a floating storage and regasification unit (FSRU) at a dedicated berth in the Port of Matola and has received strong interest from shipowners, many of which have been negatively affected by the deferment or delay of projects as a result of the Covid-19 pandemic.

In fact, Herai says the availability of an FSRU is no longer seen as a critical-path item given recent market developments and the focus currently is on securing the best possible commercial value, which could assist in lowering the overall cost of the project.

The harbour itself has recently been dredged to sufficient dimensions for handling the LNG vessels; a fact that has been confirmed through navigation studies and detailed simulations. Most of the Total LNG fleet is made up of vessels able to carry 170 000 m3 of LNG. Some minimal dredging will be required for a new turning circle and berthing pocket as the LNG terminal will be located at a last berthing dock in the harbour.

“We see this project as a game-changer for gas and potentially gas-to-power in Southern Africa. There is currently insufficient natural gas supply for market growth and the power generation needs in Southern Africa; a scenario that is likely to worsen as output from the Pande and Temane gas fields declines,” De Vos asserts.

“The Matola gas terminal is also ideally placed to supply regasified LNG to industrial customers, while its proximity to the existing high-voltage Motraco interconnector means that gas can begin to play a more significant role as a complement to renewable energy power plants in between South Africa and Mozambique,” Herai concludes.

Interested parties can provide their gas and power demand information on the BGC website: www.bgc.co.mz

This post is sponsored by Festac News Press Limited


Digital Transformation in Oil & Gas—How to Choose the Right Partners?

PAID POST

Low oil prices, combined with the COVID-19 pandemic, are putting pressure on oil and gas companies to reduce operational costs through efficiency and optimization. There is only a limited number of ways to achieve this — by downsizing, reducing production, or implementing digital transformation. While a quick fix, downsizing and production reduction are not sustainable solutions. As such, more and more oil and gas companies are looking at the strategic advantages of digital transformation, driven by cloud computing, Internet of Things (IoT), big data, and Artificial Intelligence (AI).

Digitization: A Must for the Oil and Gas Industry

According to Accenture Technology Vision 2019, of the 168 oil and gas executives surveyed, 85% from upstream and 90% from downstream companies said that they were currently implementing one or more of the following technologies: Distributed Ledger Technology, AI, Extended Reality, and Quantum Computing (DARQ).

In recent years, most large oil and gas companies have increased investment in digital transformation. Internationally, large multinationals have launched their own digital and intelligent oilfield construction plans, such as the Digital Oilfield by ExxonMobil, Integrated Development by ConocoPhillips, Smart-Field by Royal Dutch Shell, I-Field by Chevron, and E-Field by BP.

Chinese enterprises have also been actively implementing new digital strategies in the industry. China National Petroleum Corporation (CNPC) has built an exploration and production cloud platform, as well as over 50 digital management systems, including exploration and development, refinery and chemical engineering, and service support, among others. Sinopec has set up three digital platforms for operation management, production operation, as well as information infrastructure and O&M. In addition, it has built several technology-driven solutions, such as ProMACE, smart factory, Chememall, and Epec. At the same time, China National Offshore Oil Corporation (CNOOC) is developing on-going plans for intelligent oilfields. It has successfully built unmanned platforms, and has piloted multiple projects on intelligent exploration, oil production, asset management, and drilling and completion.

Oil and gas companies are rapidly investing in digital and intelligent projects to improve exploration and development efficiency and reduce production costs. Ultimately, the industry looks to seize the opportunities that digital transformation has to offer.

A Difficult Road to Digital Transformation

Each upstream enterprise progresses at a different pace during digital transformation. Various companies in the oil and gas industry have achieved different levels of development in data monitoring and collection, device networking, data analysis, and predictive maintenance; the industry overall has had some success in these domains. However, the further the industry transforms digitally, the more challenges it faces.

Zhang Tiegang, former Deputy Chief Engineer of Daqing Oilfield Exploration and Development Research Institute, introduced the three key pain points in the digital transformation of the oil and gas industry at the Huawei Oil and Gas Virtual Summit 2020 held on July 15.

  1. Massive Data Growth

Compared with other industries, oil and gas manages an even larger amount of data. For example, the amount of seismic data is increasing at an unprecedented speed. As oil and gas exploration becomes more difficult, the process requires more precise seismic wave exploration techniques. Broadband, wide-azimuth, and high-density (BWH) seismic data collection is particularly important, amounting to nearly 1 TB/km2. The exploration area is constantly expanding and the originally collected high-resolution seismic data in just a single work area may amount to over 17 TB. In addition, the continuous increase in historical data records further speeds up data growth.

  1. Increased Computation Workload and Complexity

The ever-increasing data volume leads to a sharp increase in the computation workload. For example, the computation workload of pre-stack reverse time migration (RTM) and storage volume are 10 and 50 times higher than before, respectively. To ensure comprehensive and accurate understanding of oilfield production dynamics, the computation requirements of large-scale reservoir numerical simulation also increase significantly. Therefore, oilfield companies have increasingly high requirements on data processing technologies. More and more complex algorithms — such as anisotropic pre-stack depth imaging, RTM, and full waveform inversion (FWI) — also pose higher requirements on computational capabilities.

  1. Weak Information Infrastructure

Equipment rooms, computing, storage, and IT O&M constitute the information infrastructure system of oil and gas enterprises. Most companies used to build their own, resulting in many equipment rooms with high energy consumption and low security. At the same time, low server configuration and utilization are no longer able to meet the requirements of massive data processing. In addition, the existing shared storage devices come from different providers and feature low capacity, unable to store massive data. Moreover, O&M departments face increasing pressure to hire highly skilled personnel to ensure the O&M of independent and scattered IT with a poor intelligence level.

Partnership Can Help Oil & Gas Streamline Digital Transformation Who Will the Partners Be?

The digital transformation of oil and gas enterprises is a huge systematic undertaking. Therefore, technical support from IT companies is indispensable.

Partnership Between Oil and Gas Enterprises and IT Companies (Some Cases)

Every large oil company has chosen to form partnerships for digital transformation. In this case, IT companies provide oil and gas enterprises with comprehensive digital solutions by using advanced technologies such as AI, big data, and cloud computing.

Take the partnership between Huawei and Daqing Oilfield Company as an example. Cloudification is key for digital transformation. However, data, computing, and facilities present serious challenges. To address these, Daqing Oilfield Company cooperated with Huawei to build a cloud data center, achieving an elastic supply of IT resources. The computing power of the data center now reaches 1,000 trillion FLOPS — a 300% increase in efficiency. Thanks to the elastic supply of computing and storage resources, the acquisition period has been reduced from three days to three hours. At the same time, servers with super computing power and the cloud-based deployment environment optimize data processing by 3 to 10 times. To achieve this, production data is transmitted to the cloud center through the high-speed dedicated network for processing. The calculation results are automatically sent back to the data center for archiving and management, ensuring the security of the core oilfield data.

In addition, Huawei has developed multiple technical service capabilities for oilfield digitization by using technologies such as AI, big data, and 5G. By deploying HUAWEI CLOUD, SONATRACH (Algeria) has successfully transitioned to cloud-based IT by deploying a company-wide ERP system. With AI, big data, and industrial IoT technologies, Huawei has built a fault prediction model for predictive maintenance of pumping units. Huawei has also built the largest industrial 5G oilfield lab in Europe’s biggest oil refinery, as well as implemented future-oriented services such as inspection robots, wireless sensors, “connected” employees, and predictive maintenance. Recently, Shengli Oilfield and Huawei recently signed a strategic cooperation agreement to build a cloud platform and 5G-based intelligent oilfields.

Efficiency and cost are the competitiveness indicators of the oil and gas industry. As a leading global ICT solutions provider, Huawei is continuously working with oil and gas partners to reduce costs, increase efficiency, and achieve digital transformation.

  1. Improved efficiency

In line with the strategy of increasing reserves and production, how to maximize value from historical exploration and development data has become a new requirement of CNPC. Together with partners, Huawei planned and built a computing AI platform for CNPC, to implement AI training and big data analytics. The customer has now applied AI in multiple ways, such as artificial lift fault diagnosis and seismic first arrival wave identification. The value of underused historical exploration and production data has been fully explored.

  1. Reduced cost

Huawei built a local, dedicated cloud for Daqing Oilfield, to provide oil and gas exploration computing. This in turn helped Daqing to optimize its costs and shift high-performance exploration and development computing services from CAPEX to OPEX. By reusing ten PB of historical exploration data, the cloud helped improve computing power by 833 percent, and increase the annually processed area from 400 square kilometers to 2000 square kilometers.

Strong partnerships are essential in the oil and gas industry, regardless of the digital transformation strategies a company may adopt. Alone, digital transformation is difficult, due to its complex technical requirements. The key for success is to build strong and strategic partnerships with industry leaders, ensuring a clear scope of cooperation. In this period of digital transformation, it is critical for oil and gas enterprises to choose their partners wisely — it will define the industry trends, but more importantly, it will determine who will become the new industry leaders.


Welltec: Embedding Automated Processes in Manufacturing

PAID POST

The Welltec Annular Barrier WAB®, a flexible, high performance production parker, is one of the results of a 26year long series of innovations which began with the Well Tractor® , the conveying device that launched Welltec in place as a top draw subsurface solutions service provider.

The company’s Development and Engineering (D&E) department is responsible for bringing new ideas to life and transforming innovation into reality. It is this ability to think differently and then do differently that forms the foundations on which Welltec is built. The company manufactures her products in-house, embedding automated processes to proffer completions and interventions solutions.

The main Manufacturing sites are based in Denmark with Intervention services produced in Allerød, a small community just north of Copenhagen, and Completion products made in Esbjerg, the Danish oilfield hub.

Below are pictures from a recent tour to the company’s facilities at Allerød and Esbjerg.


 

 


Advertisers’ Announcement-Petroboost Technology Enables Viscous Oil To be Readily Produced

Revolution Minerals Ltd has recently introduced a revolutionizing technology in boosting oil and gas well production– PetroBoost®, a patented method for exerting a combined effect on the near-wellbore region of a producing formation.

PetroBoost technology is the result of many years of scientific research and lab testing by leading Russian and Ukrainian scientific institutes focused on research into hydrogen energy.

PetroBoost technology has been successfully tested in collaborations with major oil and gas companies in a broad variety of wells with differing geological conditions. These companies include Gazprom, Novatek, Tatneft in Russia, Eni SPA in Turkmenistan and others.

The PetroBoost technology effectively enhances well production increasing ultimate recovery factors of oil and gas reservoirs. PetroBoost technology is effective in oilfields where traditional stimulation technologies struggle, including viscous oil, those with high paraffin content, oil rims, tight formations, etc.

 

 

 

 

 

 

Contacts:

Address: 86-90 Paul Street, London EC2A 4NE, United Kingdom

Phone: +44 (0) 203 695 2948

E-Mail: info@revolution-minerals.com

 


Advertiser’s Announcement: OILSERV Ltd Commences Massive AKK Pipeline Project

Nigeria is finally on the verge of unlocking huge economic benefits arising from its natural gas endowment. For many years, the country had been hindered by absence of gas transmission pipelines in her bid to harness its abundant gas reserves for provision of gas to generate electricity, and stimulate rapid industrialization using gas as feedstock for fertilisers, ammonia and other petrochemical applications.

The commencement of the NNPC-sponsored Ajaokuta–Kaduna–Kano (AKK) Gas Pipeline project by leading indigenous EPC giant – OILSERV Limited is the cause for this renewed optimism. OILSERV has been awarded the engineering, procurement, construction, installation, testing, and commissioning of the first segment of the 614 km x 40-Inch Gas pipeline, which is from Ajaokuta to mid-way between Abuja and Kaduna. The second segment has been awarded to another company.

Information available to us shows that OILSERV has achieved significant progress in a short spate of time including ongoing detailed engineering design, topographical and geotechnical surveys, haulage and stacking of line pipes in preparation to commence construction activities.

In the words of the Group Managing Director of NNPC; Melle Kolo Kyari “the AKK project is key to resolving the power deficit challenge of the country. Its multiplier effect on the economy and provisions of jobs will be unprecedented. NNPC will give all necessary support to the Contractors to enable them deliver the project within time and within budget”.

Chairman of OILSERV Ltd, Engr. Emeka Okwuosa, gave a pledge that OILSERV will leave no stone unturned to partner with NNPC and make the dreams of 200million Nigerians come true by delivering the AKK project to global quality and standards. In his words, “The capability of OILSERV has been honed in the course of successful delivery of landmark EPC contracts such as lot B of the 48inch OB3 gas pipeline system that is currently being commissioned”.

The optimism and hope that this development represents is a clear elixir that is surely needed by the entire nation at this time. We wish OILSERV, NNPC and everyone else involved in this endeavor, success.


CGG Completes Seismic Imaging of Mozambique’s Zambezi Delta

CGG has announced the completion of three-dimensional(3D) Pre-Stack Depth Migrated(PSDM) seismic dataset from its recent 15,400 sq km multi-client survey of the outer Zambezi Delta in the Mozambique Basin.

The data is now available for licence.

The seismic information was acquired over blocks Z5-C andZ5-Dand surrounding open acreage as part of a multi-client programmeagreed between CGG and Mozambique’s Instituto Nacional de Petroleo (INP).

“The final PSDM data identifies key stratigraphic intervals for a better understanding of the petroleum system and, in conjunction with the high-resolution gravity and magnetic data, brings new information on the basin morphology and its evolution”, CGG says in a statement, adding that its advanced imaging workflow, “including full-waveform inversion (FWI), reveals a high level of detail in this complex geological setting, such as the complex deep marine turbiditic system and associated frontal splays, and the complex faulting pattern and internal architecture of the Beira High”.

CGG’s media relations unit explains that a complementary Mozambique JumpStart™ package is also now available to license with the PSDM seismic data, in order for clients to experience an enhanced exploration decision-making,.“This package provides an integrated geoscience analysis ofall theregional data available and frames itin its geological context in an easily accessible format.

“Data from 11 wells has been analyzed in detail alongside the new seismic interpretation which was supported by hydrocarbon seep identification, high-resolution potential fields data and the full suite of Robertson multi-client geological data sets”.


Prime Atlantic Has Vacancies for Engineers and Geoscientists

PAID POST/ADVERTORIAL

Prime Atlantic, a service provider in Nigeria’s E& P sector, has published a document offering jobs to experienced Electrical and Mechanical engineers, as well as skilled Geoscientists.

The company wants

  • Engineer: Electrical Lead III

Qualification: BSc, BTech or HND in Electrical Engineering

  • Geophysical Quality Control Representative

Qualification: BSc or MSc in Geophysical or Geotechnical Field

  • Engineer: Mechanical Lead III

Qualification: BSc, MSc in Mechanical Engineering

And

  • Geoscience Technical Quality Control

Qualification: BSc or MSc in Geophysical or Geotechnical field

The minimum experience is 10 years

The details of the offer are provided in this link.

Offer loses January 28, 2020.

© 2020 Festac News Press Ltd..