Future Proofing the Development of Unconventional Resources in UAE

2021 ◽  
Author(s):  
Viannet Okouma Mangha ◽  
Nabila Lazreq
Keyword(s):  
North America ◽  
Service Sector ◽  
Oil And Gas ◽  
Gas Production ◽  
Lessons Learned ◽  
Energy Information Administration ◽  
Resource Base ◽  
Unconventional Resources ◽  
The Usa ◽  
Resources Development

Abstract The growth of USA shale oil and gas production over the last decade has been nothing short of phenomenal. In 2012 shale gas comprised 39% of US natural gas output, and by 2040, nearly 80% of total gas production is anticipated to come from unconventional resources. In April 2021, in the USA alone, gas production from major unconventional plays reached 83.0 BCFD and oil production was 7.6 MMBD. Driven by rising gas demand and advances in geosciences, drilling and completion technology (hydraulically fractured horizontal wells), unconventional plays have become eminent in the global energy supply, both for value and volume. The development of unconventional resources in North America was aided by governmental positive policies and taxes preferences, the readily available infrastructure, a vast service sector, advanced technologies and expertise, and general understanding of sweet spots due to numerous well penetrations. Following the above accomplishments: exploration, development, and production success in North America, particularly in the USA unconventional basins, several Majors and Independents have been trying to expand the opportunities outside of North America and other countries such as UAE, Oman and Saudi Arabia have been booking significant unconventional resources. For these reasons, the USA and Canada represent the ‘reference benchmark’ by which countries similarly endowed with shale resources can be evaluated. Abu Dhabi recently announced, in 2019 and 2020, discoveries of 160 TCF of unconventional gas, an estimated 22 billion STB of recoverable unconventional oil resources, both located onshore. These finds have pushed the UAE to the sixth position globally in terms of hydrocarbon reserves, from seventh, according to data listed by the US Energy Information Administration (EIA). Developing these resources are an integral part of ADNOC 2030 strategy of "Monetize our hydrocarbon resources" and becoming gas self-sufficient by 2030. North America achievements in unconventional resources development has triggered other countries to evaluate their unconventional resources. This has come with mixed results: failures in Ukraine, Poland and successes in Argentina. UAE has world class unconventional resource base which development raises the challenges of what practices worth replicating (PWR) need to be adopted by UAE and in turn ADNOC. Some lessons learned, thus practices worth replicating (PWR) can be tailored and adopted from the success of unconventional resources development in North America, will be described in this paper as a benchmark for progressing unconventional resources development in UAE.

Chemical Deliquification of Unconventional Gas Wells

2014 ◽  
Author(s):  
K.. Francis-LaCroix ◽  
D.. Seetaram
Keyword(s):  
Natural Gas ◽  
Best Practice ◽  
Oil And Gas ◽  
Large Deviation ◽  
Cost Effective ◽  
Gas Production ◽  
Lessons Learned ◽  
Offshore Platforms ◽  
Gas Wells ◽  
Current Production

Abstract Trinidad and Tobago offshore platforms have been producing oil and natural gas for over a century. Current production of over 1500 Bcf of natural gas per year (Administration, 2013) is due to extensive reserves in oil and gas. More than eighteen of these wells are high-producing wells, producing in excess of 150 MMcf per day. Due to their large production rates, these wells utilize unconventionally large tubulars 5- and 7-in. Furthermore, as is inherent with producing gas, there are many challenges with the production. One major challenge occurs when wells become liquid loaded. As gas wells age, they produce more liquids, namely brine and condensate. Depending on flow conditions, the produced liquids can accumulate and induce a hydrostatic head pressure that is too high to be overcome by the flowing gas rates. Applying surfactants that generate foam can facilitate the unloading of these wells and restore gas production. Although the foaming process is very cost effective, its application to high-producing gas wells in Trinidad has always been problematic for the following reasons: Some of these producers are horizontal wells, or wells with large deviation angles.They were completed without pre-installed capillary strings.They are completed with large tubing diameters (5.75 in., 7 in.). Recognizing that the above three factors posed challenges to successful foam applications, major emphasis and research was directed toward this endeavor to realize the buried revenue, i.e., the recovery of the well's potential to produce natural gas. This research can also lead to the application of learnings from the first success to develop treatment for additional wells, which translates to a revenue boost to the client and the Trinidad economy. Successful treatments can also be used as correlations to establish an industry best practice for the treatment of similarly completed wells. This paper will highlight the successes realized from the treatment of three wells. It will also highlight the anomalies encountered during the treatment process, as well as the lessons learned from this treatment.

scholarly journals Effectiveness of Tax Incentives of Hard-To-Recover Oil Reserve Development

2019 ◽  
Vol 8 (10S) ◽  
pp. 399-403
Keyword(s):  
Oil And Gas ◽  
Tax Incentives ◽  
Gas Production ◽  
Market Development ◽  
Oil And Gas Production ◽  
Technological Breakthrough ◽  
Tax Incentive ◽  
The Usa ◽  
Geological Formations ◽  
Oil And Gas Sector

The present-day stage of the world hydrocarbon market development is characterized by the growing share of oil and gas production from the fields related to hard-to-recover reserves in terms of different criteria, which is a consequence of technological breakthrough in the USA. The strategic task of Russian oil and gas sector is to intensify the development of such fields with governmental support in the form of tax incentives. The goal of this research is to consider dynamics of oil production from the fields related to Bazhenov, Abalak, Domanic, and Khadumsk geological formations with enormous hydrocarbon potential thanks to tax incentives. The research method used is statistical analysis. The research results have shown the effectiveness of tax incentives, but due to absence of native development technologies, the effectiveness of incentives is evened, which requires different approaches to the tax incentive system.

Shaping the decommissioning landscape of tomorrow

2020 ◽  
Vol 60 (2) ◽  
pp. 537
Author(s):  
Andrew Taylor
Keyword(s):  
Service Sector ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Industry Growth ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Research Organisations ◽  
Growth Centres

Associated with the growth of Australia’s oil and gas industry over the past 40 years, our oceans currently host oil and gas production and transportation infrastructure that will cost ~AU$30 billion to decommission. National Energy Resources Australia (NERA) is one of six industry growth centres (IGC) funded by the Australian Government. NERA is investigating opportunities for transforming the way that Australia manages its upcoming decommissioning activities. In 2019, NERA undertook a series of stakeholder consultations to refresh our understanding of Australia’s decommissioning outlook. Feedback was received through more than 20 interviews and follow-up surveys with the service sector, operators, research organisations, regulators and consultants. This paper highlights the outcomes of this review and NERA’s view on opportunities to position Australia favourably to manage decommissioning in a way that maximises benefits.

scholarly journals Caspian or Arctic region: that is the question…

2020 ◽  
Vol 6 (4) ◽  
pp. 427-437
Author(s):  
S. Y. Chernitsyna
Keyword(s):  
Legal Status ◽  
Oil And Gas ◽  
Arctic Region ◽  
Gas Production ◽  
Lessons Learned ◽  
The Arctic ◽  
Caspian Region ◽  
The Caspian Sea ◽  
Oil And Gas Production ◽  
The Arctic Region

The article compares the problems of two strategically important regions for Russia — the Caspian region and the Arctic region. Despite the fact that there are some significant geographical and climate differences, the geopolitical situation in the regions is similar. There are almost identical risks in the development of these regions. Special attention is paid to the issue of ecology in the conditions of active oil and gas production. The question concerning the instruments of regulation of interstate relations is sharply raised. International cooperation is essential in addressing key issues in the regions, such as improving socio-economic conditions, energy distribution and border management. In particular, it is necessary to define a regulatory framework that would meet the new realities in the Arctic. As for the international legal status of the Caspian sea, it was settled by the adoption of the Convention following the summit in 2018. The main difference is that the Caspian region was exposed to the anthropogenic factor much earlier. The lessons learned from the work in the Caspian region can be used in the Arctic region, which can reduce some of the risks associated with the interaction of coastal countries.

POROSITY GENERATION AND RESERVOIR POTENTIAL OF OULDBURRA FORMATION CARBONATES, OFFICER BASIN, SOUTH AUSTRALIA

1995 ◽  
Vol 35 (1) ◽  
pp. 106 ◽  
Author(s):  
M.R. Kamali ◽  
N.M. Lemon ◽  
S.N. Apak
Keyword(s):  
Oil And Gas ◽  
South Australia ◽  
Gas Production ◽  
Burial Diagenesis ◽  
Secondary Porosity ◽  
Oil And Gas Production ◽  
Shallow Marine ◽  
Subaerial Exposure ◽  
The Usa ◽  
Reservoir Potential

Porosity generation and reservoir potential of the early Cambrian Ouldburra Formation in the eastern Officer Basin is delineated by combining petrographical, petrophysical and sedimentological studies. The shallow marine Ouldburra Formation consists of carbonates, mixed carbonates and clastics, clastics and evaporites. Detailed analysis of more than 100 samples shows that dolomitisation resulted in substantial secondary porosity development within the carbonates. Secondary porosity has also been generated within the mixed siliciclastic-carbonate zone by carbonate matrix and grain dissolution as well as by dolomitisation. Prospective reservoir units correspond to highstand shallow marine facies where short periods of subaerial exposure resulted in diagenetic changes.Sedimentary facies and rock character indicate that sabkha and brine reflux models are applied to dolomitisation within the Ouldburra Formation. Dolomite mainly occurs in two stages: common anhedral dolomites formed early by replacement of pre-existing limestone, and saddle dolomite and coarse crystalline dolomite formed during the late stages of burial diagenesis, associated with hydrocarbon shows. The dolomite reservoirs identified are ranked on the basis of their porosity distribution and texture into groups I to IV. Dolomites with rank I and II exhibit excellent to good reservoir characteristics respectively.The Ouldburra Formation shows many depositional and diagenetic similarities to the Richfield Member of the Lucas Formation in the Michigan Basin of the USA. Substantial oil and gas production from middle Devonian shallow water to sabkha dolomites makes the Richfield Member an attractive reservoir analogue to the Ouldburra Formation.

Alaska’s North Slope May Yet See Its Renaissance in Arctic Exploration

2021 ◽  
Vol 73 (10) ◽  
pp. 17-22
Author(s):  
Pat Davis Szymczak
Keyword(s):  
Oil And Gas ◽  
Barents Sea ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Oil Field ◽  
The Arctic ◽  
Energy Information Administration ◽  
Gas Field ◽  
The Us ◽  
Arctic Exploration

It wasn’t too long ago that Arctic oil and gas exploration enjoyed celebrity status as the industry’s last frontier, chock full of gigantic unexplored hydrocarbon deposits just waiting to be developed. Fast forward and less than a decade later, the same climate change that made Arctic oil and gas more accessible has caused an about-face as governments and the world’s supranational energy companies rebrand and target control of greenhouse gases (GHG) to achieve carbon neutrality by 2050. Among countries with Arctic coastlines, Canada has focused its hydrocarbon production on its oil sands which sit well below the Arctic Circle; Greenland has decided to not issue any new offshore exploration licenses (https://jpt.spe.org/greenland-says-no-to-oil-but-yes-to-mining-metals-for-evs), and while Norway is offering licenses in its “High North,” the country can’t find many takers. The Norwegian Petroleum Directorate (NPD) reported that while 26 companies applied for licenses in 2013, this year’s bid round attracted only seven participants. Norway is Europe’s largest oil producer after Russia with half of its recoverable resources still undeveloped and most of that found in the Barents Sea where the NPD says only one oil field and one gas field are producing. That leaves Russia and the US—geopolitical rivals which are each blessed with large Arctic reserves and the infrastructure to develop those riches—but whose oil and gas industries play different roles in each nation’s economy and domestic political intrigues. Russia sees its Arctic reserves, particularly gas reserves, as vital to its national security, considering that oil and gas accounts for 60% of Russian exports and from 15 to 20% of the country’s gross domestic product (GDP), according to Russia’s Skolkovo Energy Centre. With navigation now possible year­round along the Northern Sea Route, Russia’s LNG champion and its largest independent gas producer, Novatek, is moving forward with exploration to expand its resource base and build infrastructure to ship product east to Asia and west to Europe. https://jpt.spe.org/russian­lng­aims­high­leveraging­big­reserves­and­logistical­advantages As a result, Russia’s state­owned majors—Rosneft, Gazprom, and Gazprom Neft—are lining up behind their IOC colleague as new investment in Arctic exploration and development is encouraged and rewarded by the Kremlin. In contrast, the American Petroleum Institute reports that the US oil and gas industry contributes 8% to US GDP, a statistic that enables the US to have a more diverse discussion than Russia about the role that oil and gas may play in any future energy mix. That is unless you happen to be from the state of Alaska where US Arctic oil and gas is synonymous with Alaskan oil and gas, and where the US Geological Survey estimates 27% of global unex­plored oil reserves may lie. Though Alaska is responsible for only 4% of US oil and gas production, those revenues covered two-thirds of Alaska’s state budget in 2020 despite the state’s decline in crude production in 28 of the past 32 years since it peaked at 2 million B/D in 1988, according to the US Energy Information Administration (EIA).

scholarly journals Top-down estimates of black carbon emissions at high latitudes using an atmospheric transport model and a Bayesian inversion framework

2018 ◽  
Vol 18 (20) ◽  
pp. 15307-15327 ◽  
Author(s):  
Nikolaos Evangeliou ◽  
Rona L. Thompson ◽  
Sabine Eckhardt ◽  
Andreas Stohl
Keyword(s):  
North America ◽  
Biomass Burning ◽  
Oil And Gas ◽  
Transport Model ◽  
Atmospheric Transport ◽  
A Priori ◽  
Gas Production ◽  
Anthropogenic Sources ◽  
A Posteriori ◽  
Northern Latitudes

Abstract. This paper presents the results of BC inversions at high northern latitudes (> 50° N) for the 2013–2015 period. A sensitivity analysis was performed to select the best representative species for BC and the best a priori emission dataset. The same model ensemble was used to assess the uncertainty of the a posteriori emissions of BC due to scavenging and removal and due to the use of different a priori emission inventory. A posteriori concentrations of BC simulated over Arctic regions were compared with independent observations from flight and ship campaigns showing, in all cases, smaller bias, which in turn witnesses the success of the inversion. The annual a posteriori emissions of BC at latitudes above 50° N were estimated as 560±171 kt yr−1, significantly smaller than in ECLIPSEv5 (745 kt yr−1), which was used and the a priori information in the inversions of BC. The average relative uncertainty of the inversions was estimated to be 30 %.A posteriori emissions of BC in North America are driven by anthropogenic sources, while biomass burning appeared to be less significant as it is also confirmed by satellite products. In northern Europe, a posteriori emissions were estimated to be half compared to the a priori ones, with the highest releases to be in megacities and due to biomass burning in eastern Europe. The largest emissions of BC in Siberia were calculated along the transect between Yekaterinsburg and Chelyabinsk. The optimised emissions of BC were high close to the gas flaring regions in Russia and in western Canada (Alberta), where numerous power and oil and gas production industries operate. Flaring emissions in Nenets–Komi oblast (Russia) were estimated to be much lower than in the a priori emissions, while in Khanty-Mansiysk (Russia) they remained the same after the inversions of BC. Increased emissions at the borders between Russia and Mongolia are probably due to biomass burning in villages along the Trans-Siberian Railway. The maximum BC emissions in high northern latitudes (> 50° N) were calculated for summer months due to biomass burning and they are controlled by seasonal variations in Europe and Asia, while North America showed a much smaller variability.

scholarly journals Prospects for the North America’ shale hydrocarbons development

2014 ◽  
pp. 97-105
Author(s):  
T. V. Polyakova
Keyword(s):  
North America ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Political Issues ◽  
Political Consequences ◽  
The North ◽  
Oil And Gas Resources ◽  
The Impact ◽  
The U.S

An entire generation of American politicians were concerned about the growing U.S. dependence on imported oil and natural gas. However, in the last few years the situation has changed dramatically: there was started the development of not only the resources of shale gas, but shale oil. As a result in political and economic circles they began to talk about it as the most significant breakthrough in the energy resources development since the oil boom in Texas in the late 1920s. How large are these resources? What problems have to be overcome if the available potential will be realized? How will this problems affect the U.S. energy policy? Concerns about the adequacy of regulation, in particular the environmental issues associated with the non-conventional hydrocarbons production, have led to the internal public debate on the impact of unconventional oil and gas resources mining boom. One thing is clear: significant amounts of additional oil and gas supplies in the U.S. will have far-reaching political consequences for the world. The article presents the different points of view on the prospects for oil and gas production in North America, as well as on the political issues related to it.

It's not easy to collaborate, but it's essential!

2017 ◽  
Vol 57 (2) ◽  
pp. 426
Author(s):  
Bernadette Cullinane ◽  
Paul Harrison
Keyword(s):  
Economies Of Scale ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Structural Factors ◽  
Resource Base ◽  
Gas Industry ◽  
Service Companies ◽  
Trade Offs ◽  
The Cost

While emerging as a world leader in liquefied natural gas production, overall, Australia’s oil and gas industry is disadvantaged by the remoteness and geographical breadth of our operations, our limited infrastructure and insufficient economies of scale. These factors drive up the cost of production and make it difficult for both operators and service companies to balance the trade-offs between building scale and capability. Despite our rich resource base, these structural factors make it challenging for the Australian oil and gas industry to compete globally. Additionally, traditional project development and contracting practices rely on bespoke, bi-lateral agreements between operators and service companies, resulting in inconsistencies and inefficiencies that limit the reuse of solutions and technology, driving costs even higher. This has created an imperative for new collaborative industry platforms in areas of workforce competency management and integrated activity planning, which leverage standardised processes and common infrastructure. This paper will explain how to overcome collaboration obstacles by cultivating a culture of transparency and will discuss the steps undertaken to develop trust within a diverse stakeholder group, enabling the creation of shared solutions. This paper gives concrete recommendations on how to create a new mindset around the appropriate company structure for the development of collaborative and innovative platforms that deliver more competitive outcomes to the Australian oil and gas industry.

Sign in / Sign up

Export Citation Format

Share Document