Artículo Académico / Academic Paper
Recibido: 01-05-2026, Aprobado tras revisión: 16-07-2026
Forma sugerida de citación: Ayala, E.; Prado, K. (2026). “A Review of Flare Gas Utilization for Power Generation in Oil Fields:
Technologies, Applications, and Challenges”. Revista Técnica “energía”. No. 23, Issue I, Pp. 102-110
ISSN On-line: 2602-8492 - ISSN Impreso: 1390-5074
Doi: https://doi.org/10.37116/revistaenergia.v23.n1.2026.766
© 2026 Autores Esta publicación está bajo una licencia internacional Creative Commons Reconocimiento –
No Comercial 4.0
A Review of Flare Gas Utilization for Power Generation in Oil Fields:
Technologies, Applications, and Challenges
Revisión del Aprovechamiento del Gas de Antorcha para la Generación de
Energía en Campos Petrolíferos: Tecnologías, Aplicaciones y Desafíos
E. L. Ayala1
0000-0003-2528-4380
K. V. Prado2
0009-0008-4138-5206
1 Mechatronics Engineering, Universidad Politécnica Salesiana, Cuenca, Ecuador
E-mail: eayala@ups.edu.ec, edyayalacruz@gmail.com
2 Master of Environmental Management and Eco-innovation, Universidad Politécnica Salesiana, Cuenca, Ecuador
E-mail: kpradof@est.ups.edu.ec, kari_pra@yahoo.com
Abstract
Routine gas flaring remains one of the principal
environmental and energy efficiency challenges
associated with oil production. Although associated
petroleum gas (APG) is commonly treated as a by-
product, it represents a valuable energy resource that
can be utilized for electricity generation and other
productive applications, contributing to greenhouse gas
emission reduction and improved operational
efficiency. This paper presents a structured narrative
literature review of the principal technologies available
for APG utilization, including reciprocating gas
engines, gas turbines, microturbines, combined heat and
power systems, Organic Rankine Cycle technologies,
gas reinjection, liquefied natural gas, compressed
natural gas, and gas-to-liquids processes. The reviewed
technologies are comparatively analyzed considering
their technical characteristics, operational advantages,
limitations, and suitability for remote oil-field
applications. Special attention is given to the recent
implementation of Ecuador’s Optimization of
Electricity Generation (OGE) program, which
illustrates the practical application of APG recovery
technologies under Amazonian operating conditions.
The review highlights that no single technology is
universally optimal and that successful implementation
depends on gas availability, gas quality, infrastructure
availability, and local energy demand. The findings
provide an updated technical overview that supports
future APG utilization projects in Ecuador and similar
oil-producing regions.
Resumen
La quema rutinaria de gas continúa siendo uno de los
principales desafíos ambientales y de eficiencia
energética asociados a la producción de petróleo.
Aunque el gas asociado al petróleo (APG) suele
considerarse un subproducto de la extracción,
constituye un recurso energético valioso que puede
aprovecharse para la generación de electricidad y otras
aplicaciones productivas, contribuyendo a la reducción
de emisiones de gases de efecto invernadero y al
mejoramiento de la eficiencia operacional. Este trabajo
presenta una revisión narrativa estructurada de las
principales tecnologías disponibles para el
aprovechamiento del APG, incluyendo motores
alternativos a gas, turbinas de gas, microturbinas,
sistemas de cogeneración, tecnologías de Ciclo Rankine
Orgánico, reinyección de gas, gas natural licuado, gas
natural comprimido y procesos gas-a-líquidos. Las
tecnologías revisadas se comparan considerando sus
características técnicas, ventajas operativas,
limitaciones y su aplicabilidad en campos petroleros
remotos. Se presta especial atención a la
implementación reciente del programa de Optimización
de Generación Eléctrica (OGE) en Ecuador, como
ejemplo de aplicación práctica de tecnologías de
recuperación de gas asociado en la Amazonía
ecuatoriana. La revisión pone de manifiesto que no
existe una tecnología universalmente óptima y que la
selección depende de factores específicos como la
disponibilidad y composición del gas, la infraestructura
existente y la demanda energética local. Los resultados
proporcionan una visión técnica actualizada que puede
servir de referencia para futuros proyectos de
aprovechamiento de APG en Ecuador y en otras
regiones productoras de petróleo.
Index terms— Associated petroleum gas, gas flaring,
powergeneration, oil fields, Ecuador.
Palabras clave— Gas asociado al petróleo, quema de
gas,generación eléctrica, campos petroleros, Ecuador.
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1. INTRODUCTION
Routine gas flaring remains a widespread practice in
oil production, where associated petroleum gas is burned
due to economic, technical, or logistical limitations. This
process represents a significant environmental concern,
as it contributes to greenhouse gas emissions including
carbon dioxide and methane,while also generating local
air pollutants that affect surround ing ecosystems and
communities [1, 2].
From an energy perspective, gas flaring constitutes a
considerable loss of potentially useful energy. The
associated gas that is routinely burned could be utilized
for electricity generation and other value-added
applications, thereby improving the overall efficiency of
oil production systems. Consequently, the reduction of
routine flaring has become an important objective for
both industry and policymakers.
The utilization of associated petroleum gas is directly
aligned with the United Nations 2030 Agenda in support
of the Sustainable Development Goals (SDGs),
particularly SDG 7 (Affordable and Clean Energy), SDG
13 (Climate Action), and SDG 9 (Industry, Innovation
and Infrastructure) [3]. In oil fields, recovery
technologies can transform energy waste into a useful
power source for local operations while reducing
greenhouse gas emissions and promoting more resilient
infrastructure in remote regions such as the Ecuadorian
Amazon.
In recent years, increasing research attention has been
directed toward the development and implementation of
technologies for associated petroleum gas utilization.
Among these, power generation systems have emerged
as a practical alternative, particularly in remote oil fields
where energy demand is present and gas transportation
infrastructure is limited.
This paper presents a structured narrative literature
review of the principal technological approaches for
associated petroleum gas (APG) utilization, with
particular emphasis on power generation technologies,
their applications, operational characteristics, and
implementation challenges [1, 4]. The remainder of this
paper is organized as follows. Section II describes the
review methodology, Section III presents the literature
reviewof APG utilization technologies, Section IV
discusses their applicability to remote oil-field
operations, and Section V summarizes the principal
conclusions.
2. REVIEW METHODOLOGY
This study was conducted as a structured narrative
literature review focused on associated petroleum gas
(APG) utilization pathways for power generation in oil
fields, with special attention to applications in remote and
infrastructure-constrained environments such as the
Ecuadorian Amazon. The review combined peer-
reviewed scientific literature with technical and
institutional documents in order to capture both the
technological state of the art and the practical
implementation context of APG recovery projects.
2.1 Search Strategy and Sources
The bibliographic search was conducted using
Scopus, ScienceDirect, SpringerLink, IEEE Xplore, and
Google Scholaras the main academic sources. To
complement the scientific literature with policy and
implementation evidence, technical reports and public
documents were also reviewed from institutions such as
the World Bank Global Gas Flaring Reduction
Partnership (GGFR), the International Energy Agency
(IEA), EP Petroecuador, the Ministry of Energy and
Mines of Ecuador, and Ecuadorian regulatory and
environmental authorities when publicly available.
The search process was guided by combinations of
the following keywords: “associated petroleum gas
utilization”, “flare gas utilization”, “gas flaring”, “APG
recovery”, “gas-to-power”, “flare gas power generation”,
“microturbines for APG”, “gas engines in oil fields”,
“associated gas Ecuador”, “OGE Petroecuador”, and
“gas flaring mitigation”.
2.2 Time Window and Selection Criteria
The review prioritized literature published between
2015 and 2026, with particular emphasis on recent
contributions from 2020 onward in order to capture
current technological trends, environmental concerns,
and ongoing gas-flaring reduction strategies. Earlier
sources were retained only when they were considered
necessary to describe foundational technologies,
internationally recognized benchmark projects, or the
historical evolution of Ecuador’s OGE program.
The reviewed documents were included when they
met at least one of the following criteria: (i) they
addressed gas flaring or APG utilization in oil and gas
operations; (ii) they evaluated or described power
generation technologies such as gas engines, gas
turbines, microturbines, or hybrid heat-recovery
schemes; (iii) they reported technical, environmental, or
economic indicators relevant to APG recovery; or (iv)
they provided country, project, or field-level evidence
relevant to the Ecuadorian case or to remote oil-field
applications. Documents were excluded when they
focused exclusively on unrelated natural gas topics,
lacked a clear connection to gas flaring reduction or APG
recovery, or duplicated information already captured by
more complete sources.
2.3 Analytical Approach
The selected sources were analyzed and grouped into
four main themes: (i) global trends in gas flaring and
APG recovery, (ii) APG utilization technologies, (iii)
worldwide implementations and operational benchmarks,
and (iv) the Ecuadorian OGE case and its implications for
remote oil fields.
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To strengthen the comparative value of the review, the
main technological routes were assessed using a common
set of criteria extracted from the literature, including
typical scale, electrical efficiency, gas pre-treatment
requirements, tolerance to gas composition variability,
relative capital and operational intensity, technology
maturity, and suitability for remote oil-field deployment.
This comparative framework is summarized in Table 1 and
serves as the basis for the discussion of technology
suitability under Ecuadorian operating conditions, rather
than providing a quantitative ranking of the reviewed
technologies.
3. LITERATURE REVIEW
Gas flaring and its technological transformation has
been extensively studied. It begins with a global
assessment of flaring practices, followed by a detailed
examination of the diverse recovery methods that have
transitioned from theoretical proposals to industrial
applications. By synthesizing recent academic research
and technical reports, this state-of-the-art analysis
establishes the groundwork for understanding how APG
can be effectively reintegrated into the energy value
chain, addressing the technical, environmental, and
economic variables that dictate the success of these
implementations.
3.1 Global Overview of Gas Flaring
Gas flaring has been extensively studied as a major
environmental issue in the oil industry [1, 2]. It is
currently recognized as one of the primary environmental
challenges associated with oil production. The practice is
particularly prevalent in regions with limited gas
infrastructure or where the eco-nomic value of associated
gas is not fully realized.
International studies have reported that a substantial
volume of associated gas is flared annually, contributing
significantly to global greenhouse gas emissions. This
has led to the development of international initiatives
aimed at reducing routine flaring and promoting the
utilization of associated gas [1, 4].
Despite these efforts, flaring remains persistent
because many oil fields are located far from gas gathering
infrastructure, pro-duce relatively small or unstable APG
streams, or require gas treatment before the recovered gas
can be used safely and reliably. In low-volume or
marginal fields, the economic return of conventional gas
recovery infrastructure may also be insufficient, which
explains why decentralized or modular utilization
pathways have gained increasing attention. Fig. 1
highlights power generation as a leading application for
APG recovery, reflecting the industry’s shift toward on-
site energy efficiency.
Figure 1: Global breakdown of flare gas utilization by end-
use cate-gory. Source: Adapted from [1, 2]
3.2 Global Overview of Gas Flaring
A variety of technologies have been proposed and
implemented for the utilization of flare gas. These can be
broadly classified into energy conversion, gas
processing, and reinjection methods. A simplified
illustration of hydrocarbon reservoir structure and flare
gas origins is shown in Fig. 2.
Power generation systems represent one of the most
widely studied and implemented options. Gas engines
and gas tur-bines are commonly used in medium and
large-scale applications due to their high efficiency and
operational reliability. These technologies are
particularly suitable for oil fields with stable gas
production and sufficient infrastructure.
Microturbines have gained increasing attention for
smaller-scale applications. Their compact design,
flexibility, and relatively low maintenance requirements
make them suitable for decentralized energy systems and
remote locations.
In addition to direct power generation, combined
systems incorporating waste heat recovery technologies,
such as Organic Rankine Cycles (ORC), have been
explored to enhance energy efficiency [5]. These systems
allow for additional energy recovery from exhaust gases,
improving overall system performance.
Other alternatives, including gas reinjection,
liquefied natural gas (LNG), compressed natural gas
(CNG), and gas-to-liquids (GTL) technologies, have also
been investigated. How-ever, these solutions typically
require significant infrastructure and investment, limiting
their applicability in certain contexts.
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Figure 2: Hydrocarbon reservoir structure and flare gas
origins. Source: Adapted from the original manuscript. Please
verify image source and permissions before final submission
3.3 Applications Overview in Oil Fields
The implementation of flare gas utilization
technologies has been reported in several oil-producing
regions worldwide. These applications demonstrate the
technical feasibility of converting associated gas into
useful energy.
In Ecuador, large-scale initiatives have been
developed to utilize associated gas for electricity
generation in oil fields. These projects have successfully
reduced diesel consumption and greenhouse gas
emissions, while improving energy efficiency within oil
production operations [6, 7].
However, such implementations have primarily been
focused on centralized systems in large oil fields. Smaller
or more re-mote fields often face additional challenges,
including lower gas volumes, variability in gas
composition, and limited access to infrastructure.
3.4 Applications Overview in Oil Fields
Despite the availability of various technologies, the
utilization of flare gas presents several technical and
operational challenges. One of the main issues is the
variability in gas flow rate and composition, which can
affect the performance and reliability of power
generation systems [8, 9].
Additionally, the presence of contaminants in
associated gas, such as hydrogen sulfide or heavy
hydrocarbons, may require pre-treatment processes;
therefore, system complexity and cost can increase
substantially. Economic factors also play a critical role,
as the feasibility of flare gas utilization depends on the
balance between investment costs, operational expenses,
and potential energy savings.
Logistical constraints, particularly in remote areas,
further complicate the implementation of flare gas
recovery systems, as they may require additional
infrastructure and maintenance capabilities. Fig. 3
displays a generic P&ID process diagram of an
associated petroleum gas conditioning system integrated
with an electric generator. The main functional blocks
include gas separation and scrubbing, gas cooling and
compression, fuel conditioning, and power conversion
through a reciprocating engine or turbine-generator unit.
Figure 3: Associated petroleum gas processing P&ID diagram in-
tegrated with power generation. Source: Adapted from the
original manuscript. Please verify image source and permissions
before final submission
3.5 Worldwide Implementations
This section examines several international
benchmarks in flare gas utilization, categorized by their
primary impact on the industry. The analysis
distinguishes between projects where technological
innovation and operational efficiency have been the main
drivers, and those where success has been primarily
dictated by strategic business models and robust
governmental policies. By evaluating these diverse
global experiences, ranging from large-scale power
plants in mature fields to de-centralized digital solutions,
this review identifies the critical success factors that can
be adapted to other oil-producing regions, such as the
Ecuadorian Amazon.
3.5.1 Technological Relevance and Operational
Impact
From a technical perspective, the most significant
implementations focus on the adaptability of generation
systems to the inherent variability of associated gas.
Global suppliers and operators have demonstrated the
efficacy of high-efficiency reciprocating gas engines in
critical environments [9, 3]. Such engines are
commonly integrated with gas conditioning systems and
differ from conventional diesel-based generation be-
cause they can operate on treated APG streams while
supporting modular deployment, on-site energy
recovery, and diesel displacement in oil-field
operations.
These technologies have achieved high utilization
rates in large-scale projects such as the Yuzhno-
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Priobskoye field in Russia, where gas-fired power plants
successfully replaced diesel generation [10]. The
operational impact of these cases lies in the integration
of modular compression, dehydration and
desulfurization units. This allows for on-site gas
processing, ensuring a stable, low-maintenance energy
source for pumping and drilling operations in remote
areas, significantly reducing the operational carbon
footprint [11].
3.5.2 Commercial Success and Government Support
On the other hand, the success of flare gas recovery is
closely linked to innovative business models and robust
regulatory frameworks. A landmark example of
government support is the Nigeria Gas Flare
Commercialization Programme (NGFCP), which
established an open market by auctioning gas utilization
rights to third-party investors [12]. This allowed small
and medium enterprises to implement micro-generation
solutions where primary operators found no profitability.
In the commercial sphere, the “Digital Flare
Mitigation” strategy in the U.S. Permian Basin stands
out. Companies such as Crusoe Energy utilize stranded
gas to power mobile data centers dedicated to high-
performance computing [13]. This model overcomes the
economic barrier of remote gas lo-cations where
traditional electricity demand or pipelines are absent,
turning an environmental waste into a high-demand
financial asset. Fig. 4 shows a global distribution of
selected flare gas utilization implementations.
Figure 4: Global distribution of selected flare gas utilization
implementations. Source: Adapted from the original manuscript
based on [9, 10, 12, 13]. Please verify image source and
permissions before final submission
3.6 OGE Project (Optimization of Electricity
Generation) in Ecuador
This section provides a comprehensive analysis of the
Optimization of Electricity Generation (OGE) project,
the flagship initiative for flare gas valorization in
Ecuador. The following sub-sections trace the project’s
trajectory from its inception as a strategic diesel-
replacement program to its current role as a critical
component in meeting judicial mandates for
environmental protection. By detailing its historical
evolution, current scaling efforts in key oil blocks, and
long-term operational projections, this review highlights
how the OGE project serves as a practical model for
transitioning toward reduced carbon footprint in the
Ecuadorian hydrocarbon sector.
3.6.1 Historical Context and Evolution (2009–2022)
The OGE&EE (Optimization of Electricity
Generation and Energy Efficiency) project was originally
conceived in 2009 with the primary objective of reducing
the consumption of imported diesel in Amazonian
operations. Between 2009 and 2015, Petroamazonas EP
(now merged into EP Petroecuador) generated
approximately 1.10 million MWh using associated gas,
displacing the use of 193 million gallons of diesel [14].
During this period, milestones such as the
interconnection of the Pañacocha Millennium
Community in 2014 demonstrated the technical
feasibility of using surplus gas for social development.
Despite these advancements, the system faced scalability
challenges, with persistent flaring intensity due to the
lack of modular infrastructure at isolated or remote
wellheads.
3.6.2 Current Implementation and Scaling (2024–
2026)
Currently, the project is in a critical expansion phase
driven by judicial mandates and new regulations issued
in September 2024 (Resolution No. ARCH-003/2024),
which demand the progressive elimination of gas flaring
[15]. As of August 2025, Ecuador has achieved a historic
milestone with the de-commissioning of 174 flares (165
from EP Petroecuador and 9 from private operators) [16].
Specific projects in the Pucuna and Auca Sur blocks
entered full operation in January 2026, enabling annual
savings of USD 7.7 million through on-site power
generation [17]. Furthermore, the Cuyabeno Gas
Utilization Project (Block 58) began its technical
socialization in February 2024 and is projected to reduce
357,000 tons of CO2 over the next decade.
3.6.3 Operational Status and 2030 Projections
To date, the utilization system is fully operational and
integrated within the Amazon District, with an installed
capacity projected to increase steadily to reach 64.3 MW
by the end of 2026 in the Auca, Sacha, Shushufindi, and
Indillana fields [16]. While the power generation
infrastructure is ac-tive and expanding, total system
effectiveness still faces logistical hurdles in frontier areas.
However, the implementation of new industrialization
technologies at the Shushufindi Industrial Complex to
produce LPG and natural gasoline from associated gas
reinforces the project’s operational viability, aiming to
meet the “Zero Routine Flaring” goal by 2030 in
compliance with World Bank standards [18].
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3.6.4 Comprehensive Analysis of Gas Utilization in
Ecuador
Despite the significant progress made by the OGE
project, Ecuador has not yet achieved full utilization of
its associated petroleum gas. As of early 2026, it is
estimated that the country effectively utilizes
approximately 35% to 42% of the total associated gas
produced in the Amazon region, primarily for internal
power generation and LPG production at the Shushufindi
Industrial Complex [19]. The remaining volume
continues to be flared, representing a daily loss of
approximately 100 million cubic feet (MMcfd). This
underutilization is attributed to the geographic dispersion
of mature fields and the high cost of implementing
gathering systems in marginal or low-production wells.
The discrepancy between the decommissioning of
flares and total gas utilization is a critical point of
analysis. While 174 flares have been removed, many
were located in clusters with high infrastructure
accessibility. The remaining flares are of-ten in frontier
areas where the gas-to-oil ratio (GOR) is lower, making
traditional pipeline solutions economically unfeasible.
Consequently, while current infrastructure is operating at
nearly 90% capacity, the national energy balance shows
that Ecuador still imports a significant amount of LPG
and diesel that could, theoretically, be replaced if the
recovery rate were increased to 75%, a target projected
only for the end of the decade [18, 20].
Fig. 5 illustrates the three-stage transition of
associated gas management in Ecuador. Stage 1 (Pre-
2009) highlights the environmental impact and economic
loss of routine flaring. Stage 2 (Current) shows the
implementation of modular technology and the
decommissioning of 174 flares. Stage 3 (2030 Goal)
projects the integration of the Shushufindi Industrial
Complex to achieve the Zero Routine Flaring target and
national energy security objectives.
3.7 Discussion: Technology Suitability for Flare
Gas Utilization in Remote Oil Fields
The literature shows that flare gas utilization cannot
be assessed through a single “best technology” criterion,
because the suitability of each route depends strongly on
gas volume, flow stability, gas composition,
contaminants, field remote-ness, and the existence of
local energy demand or gas trans-port infrastructure. In
this sense, the main contribution of the present review is
not only to summarize available technologies, but also to
interpret their relative suitability for re-mote oil-field
conditions, which is particularly relevant for the
Ecuadorian Amazon.
From a power-generation perspective, gas engines
remain one of the most mature and efficient options for
APG valorization when the associated gas stream is
sufficiently stable and gas conditioning can be
guaranteed. Their high electrical efficiency and modular
deployment potential make them attractive for medium-
scale on-site electricity generation, especially where
diesel displacement is a strategic priority. However, their
performance and reliability depend on controlling
contaminants, liquids, and fluctuations in gas quality. For
isolated wells with intermittent gas production, this
requirement may increase both pre-treatment complexity
and operating costs.
Microturbines, by contrast, appear especially
attractive for low-to-medium scale flare-to-power
applications in remote and dispersed fields. Although
their electrical efficiency is generally lower than that of
reciprocating gas engines, they offer important
operational advantages in contexts where compact-ness,
modularity, reduced maintenance burden, and
decentralized deployment are more critical than peak
conversion efficiency. For the Ecuadorian case, this
distinction is important because many of the remaining
flare points are not necessarily associated with large
centralized facilities, but rather with mature or
geographically dispersed assets where pipeline gathering
and large gas-processing infrastructure may not be eco-
nomically viable.
Gas turbines can be effective in larger centralized
projects with stable APG supply and existing industrial
infrastructure, but they are generally less attractive for
small remote wells due to scale sensitivity and operating
requirements. Simi-larly, ORC systems can improve the
total energy efficiency of a flare-to-power system by
recovering waste heat, but they should be interpreted as
complementary technologies rather than primary APG
utilization routes.
The literature also shows that LNG, GTL, and in
some cases CNG can play an important role in
associated-gas valorization, yet their applicability
decreases significantly when the gas source is small,
dispersed, unstable, or located in infrastructure poor
environments. These routes tend to require greater capital
intensity, more complex gas treatment, and stronger
logistics integration than decentralized electricity
generation. Asa result, while they may be viable in
selected high-volume projects, they are less likely to
become the dominant option for a broad portfolio of
remote marginal flare sites in the Ecuadorian Amazon.
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For Ecuador, the OGE experience confirms that flare
gas utilization has already moved beyond the conceptual
stage and has become part of the operational energy
strategy of the oil sector. However, the reviewed
evidence also suggests that the next challenge is no
longer proving that associated gas canbe used, but rather
determining which technologies are most suitable for the
remaining flare points that are smaller, more dispersed,
and more difficult to integrate into centralized systems.
This is where the research gap becomes clearer: public
information on Ecuador has focused primarily on large
scale achievements, flare decommissioning milestones,
and aggregated energy savings, whereas less attention
has been given to technology screening criteria, field-
level gas-quality constraints, modular flare-to-power
architectures, and the comparative suitability of engines,
microturbines, and hybrid recovery systems under
remote Amazonian conditions. Therefore, the reviewed
literature suggests that the mostpromising path for future
research in Ecuador is a field-oriented comparative
framework that combines gas characterization,
production profile analysis, infrastructure constraints,
and environmental performance criteria in order to
identify the best flare gas utilization route for each type
of oil-field condition. Such work would complement the
present review and provide a more direct bridge toward
future simulation, optimization, and mechatronic system
design studies
4. CONCLUSIONS
This review examined the current state of flare gas
utilization technologies for power generation in oil fields,
with emphasis on their applicability in remote operating
environments and on the Ecuadorian OGE context. The
literature confirms that flare gas valorization is no longer
a purely environmental aspiration, but an increasingly
practical energy strategy for reducing routine flaring,
improving operational efficiency, and decreasing diesel
dependence in oil production systems. From a
technological standpoint, the review shows that gas
engines, gas turbines, and microturbines remain the most
relevant routes for flare-to-power applications, although
their suitability varies substantially with field conditions.
Gas engines offer high electrical efficiency and strong
commercial maturity, making them particularly attractive
in medium-to-large projects with relatively stable APG
supply and adequate gas conditioning. Microturbines, in
turn, appear especially promising for small-scale,
modular, and decentralized applications, where remote-
field deployment, compactness, and operational
flexibility are more critical than maximum conversion
efficiency. Gas turbines remain more suitable for larger
centralized projects, while ORC systems are best
interpreted as complementary efficiency-enhancement
technologies rather than primary APG utilization routes.
The review also indicates that LNG, CNG, GTL, and
reinjection can be valid associated-gas management
pathways, but their practical suitability depends strongly
Figure 5: Evolutionary roadmap of the OGE Project in the Ecuadorian Amazon: from routine flaring to integrated
energy assets. Source: Prepared by the authors (2026), based on technical data from EP Petroecuador [17], Ministry of
Energy and Mines [19], and the World Bank Global Gas Flaring Tracker [18]
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Edición No. 23, Issue I, Julio 2026
on project scale, gas stability, infrastructure availability,
and economic context. In dispersed or low-volume oil-
field settings, especially in re-mote Amazonian
operations, these routes are generally less flexible than
direct gas-to-power alternatives and may require
substantially higher capital investment and logistics
complexity.
In the Ecuadorian case, the OGE program demonstrates
that associated gas utilization has already produced
relevant operational benefits through the replacement of
diesel-based generation and the progressive reduction of
routine flaring in selected oil blocks. However, the
evidence reviewed in this manuscript also suggests that
the main remaining challenge lies in the fields that are
smaller, more dispersed, and less accessible, where
conventional centralized solutions may not be sufficient.
For these conditions, the most relevant decision is not
whether flare gas should be utilized, but which technology
is best suited to the gas volume, variability, contaminants,
and remoteness of each field.
The main research gap identified is the limited
availability of field-level comparative assessments
tailored to Ecuadorian Amazon conditions, particularly
those integrating gas characterization, technology
selection criteria, operational constraints, environmental
performance, and decentralized power-generation
alternatives. Future research should therefore move
toward techno-economic and environmental screening
frameworks, sup-ported by simulation and field-
informed data, to determine when gas engines,
microturbines, hybrid systems, or other valorization
routes provide the most robust solution for each flare gas
source. The findings presented in this review may also
serve as a reference for future APG utilization initiatives
in Ecuador and other oil-producing regions facing similar
technical and infrastructure constraints.
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[3] United Nations, “Transforming our world: the 2030
agenda for sustainable development,” A/RES/70/1,
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Edy Leonardo Ayala Cruz was
born in Cuenca, Ecuador, in 1987.
He received the Ph.D. degree in
Engineering Sciences from the
University of Ferrara, Italy, the
Master of Engineering Science
degree from Swin-burne University
of Technology, Australia, and the
B.Sc. degree in Electronic Engineering from Universidad
Politécnica Salesiana (UPS), Ecuador. He is currently a
Research Professor and Director of the Mechatronics
Engineering Program at Universidad Politécnica
Salesiana. His research interests include associated
petroleum gas utilization, renewable energy systems,
industrial automation, intelligent control, digital twins,
artificial intelligence, and mechatronic systems applied
to sustainable energy.
Karina Valeria Prado Farfán was
born in Cuenca, Ecuador. She
received the B.Sc. de-gree in
Environmental Engineering from
Universidad Politécnica Salesiana,
Ecuador, and holds a Master’s
degree in Territorial Planning. She is
currently pursuing a Master’s degree
in Environmental Management and Eco-Innovation. She
has professional experience in environ-mental
consulting, environmental impact assessment, and
regulatory compliance for industrial and energy projects.
Her research interests include environmental
management, sustainability, associated petroleum gas
utilization, and climate change mitigation.
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