Petroleum Operations Research Articles

Politics of International Oil Companies (IOCs): Understanding PETRONAS Carigali Nile Ltd Exit From South Sudanese Oilfields

The study has examined the politics of the International Oil Companies (IOCs), the case study of PETRONAS Carigali Nile Ltd. It does this by appraising the legal violations of PETRONAS Carigali Nile Ltd exit and farming out from South Sudanese oilfields. The study explains the politics of IOCs and particularly, PETRONAS Carigali Nile Ltd as dependent variable and independent variables such as legal violations of Petronas Carigali Nile Ltd, types of residual liabilities and responsibility of these liabilities.The study was subjected to stringent empirical literature review and the gaps in the literature were filled through fieldwork. During fieldwork, the methodology of research tools and instruments such as questionnaires and interview guides/schedules were deployed with target of 52 respondents. Persuasive and cluster type of sampling amongst the senior staff of Ministry of Petroleum (MOP), Nile Petroleum Corporation (NILEPET), Dar Petroleum Operating Company (DPOC), Sudd Petroleum Operating Company (SPOC) and Greater Pioneer Operating Company (GPOC) were applied. The study findings indicate that PETRONAS Carigali Nile Ltd has politicized and violated sections 12, 22, 23, 24, 41 & 42 of the Petroleum Act 2012. Various types of liabilities such as cost recovery audits, environmental audit, petroleum taxes, surface rentals, and cash calls should be taken care off by Petronas Carigali Nile Ltd or by a company that farms into its shares. While the study concludes that PETRONAS Carigali Nile Ltd exit and farming out has been politicized and violated the laws of the Republic of South Sudan, the study recommends that the Ministry of Petroleum should be held responsible for all the legal violations Petronas Carigali Nile Ltd have committed in South Sudan without any action. Whether Savannah Energy Ltd farms into Petronas Carigali Nile Ltd shares or not after the PETRONAS has exited, consequences should be rolled out for such violations so that no any other IOC can do it again in the near future in this volatile oil and gas industry.

Flow regime transition maps and pressure loss prediction of gas, oil and water three-phase flow in the vertical riser downstream 90° bend using data driven approach

The simultaneous flow of gas, oil & water is frequently encountered in pipelines during upstream petroleum operations. The multiphase flow results in different types of flow patterns based on the flow rates of fluids, physical properties and geometry of the flow domain. The flow behavior is characterized based on the governing flow patterns. Hence, the information about the flow patterns, regime maps and resulting pressure loss are important for multiphase flow system design and optimization. The current work is focused on construction of gas, oil and water, three-phase flow regime maps and developing pressure loss prediction correlations for the flow through vertical riser downstream 90° bend. The pipe internal diameter (ID) is 6 inch and the bending radius to pipe diameter ratio is 1. The observed gas-liquid flow patterns are slug, churn, and semi-annular churn flow at the given range of superficial velocities of fluids. The flow pattern data has been used to construct flow regime maps to analyze the variation in flow patterns with flow rates of fluids and compared with the available works in the literature. In addition, the change in pressure loss with respect to flow patterns has been analyzed. Previous models are used for the prediction of pressure loss. However, according to the assessment, the models underpredicted the pressure loss. Based on three-phase pressure loss data, multiple linear regression analysis has been carried out to propose new correlations for pressure loss prediction. Comparison of the calculated and experimental data showed good agreement between the results. The knowledge of flow regime variation and pressure loss correlations can help flow assurance engineers in designing and optimization of multiphase flow systems.

Effects of operators’ strategic approach to local content and in-country spending requirements on financial performance of upstream petroleum sector firms, Ghana

Local content requirements and in-country spending mandates have emerged as crucial tools in the upstream petroleum sector, aiming to distribute socio-economic benefits derived from resource production to the general citizenry within the host economies. However, understanding how operators' strategic responses to these requirements affect firm financial performance remains limited due to data constraints. Consequently, drawing on resource dependence, social exchange, and linkage and spill-over effect theories, this paper develops a conceptual framework to elucidate the relationships among local content requirements, in-country spending, local linkage factors, operators' strategic approaches & business practices, and financial performance, including their implications. To address data limitations, a mixed-methods approach was adopted, combining content analysis of financial reports from 11 global upstream petroleum operators in Ghana and key informant interviews, with survey primary data collected via online questionnaires. This methodological triangulation enabled a comprehensive examination of how operators' strategic responses affect financial performance in the Ghanaian upstream petroleum sector. Analytical techniques used included factor analysis and Partial Least Squares Structural Equation Modeling (PLS-SEM) from SPSS and SmartPLS3, respectively. The study found that while local content requirements and in-country spending mandates do not significantly influence operator strategic approaches or financial performance, local linkage factors have a strong positive effect on strategic approaches, which in turn positively affect financial performance. Furthermore, local linkage factors partially mediate the relationship between local content requirements and strategic approaches, as well as financial performance. These findings underscored the importance of prioritizing investments in local linkage factors to stimulate industrialization and foster cross-sectorial outsourcing opportunities. The study contributes to resource dependence, social exchange, and linkage and spill-over effect theories by highlighting the role of strategic approaches and local linkages in promoting financial performance. It also offers insights for policymakers and industry practitioners, emphasizing the need to enhance competitiveness and capacity within the host economy. Additionally, the study confirms the predictive relevance of the model, indicating its robustness in explaining the dynamics of local content requirements and in-country spending mandates in the petroleum sector.

Petroleum Industries and Its Impact of Petroleum Extraction on the Environment

The petroleum sector has prioritized reducing the environmental effect of its activities in response to the growing environmental conservation movement. Personnel in the sector need to be properly educated and trained in order to safeguard the environment. The environmental effects of petroleum operations and strategies to reduce them are the subject of a wealth of valuable information. However, this information is dispersed throughout thousands of books, reports, and papers, making it challenging for industry personnel to find specific details on mitigating the environmental effects of specific operations. The breadth and complexity of environmental concerns confronting the petroleum sector can be daunting for many engineers. While a large number of outstanding papers have been given on particular environmental topics, there is still a need for overview papers that set the stage for those more in-depth investigations. This review article examines the main upstream petroleum industry waste sources, the effects those wastes have on the environment, waste management, treatment, and disposal strategies, and contaminated site cleaning techniques.

Możliwe zastosowanie energii słonecznej do zasilania operacji wydobycia węglowodorów i metod wspomagania wydobycia ropy naftowej na dużych szerokościach geograficznych

As the world enters the renewable revolution, it is crucial for the petroleum industry to remain relevant in the public eye and become environmentally awareness. One potential path to achieve these goals in a progressive and beneficial way is to integrate renewable energy sources into various nodes of the petroleum industrial operations. Different ways of achieving such integration are described in the review section of the article. These include utilizing solar energy to power upstream operations and a variety of enhanced oil recovery projects, such as microbial enhanced oil recovery and others, or using solar energy downstream to supply power to pumps, gas lift apparatus, etc. The article also proposes a novel potential application of solar energy to power operations and provide long-term sustainable energy source to petroleum operations in high latitudes. The potential applicability of solar power in petroleum engineering operations far North has long been neglected due to potential unprofitability and difficulty of construction of solar power grid in such harsh climactic conditions. However, now, as the world transitions to a new reality of co-existence of fossil fuels with alternative energy sources in light of growing concerns over climate change, it is a strategic time to implement the technology in profitable and environmentally conscious way in countries that have a trustworthy environmental record and strong, robust environmental policies, like Canada, as well as in less environmentally achieving countries with milder emission reduction targets such as Russian Federation.

Climate risk assessment in petroleum operations: A review of CSR practices for sustainable Resilience in the United States and Africa

Climate risk assessment has emerged as a critical component in the sustainability efforts of petroleum operations, given the increasing frequency and severity of climate-related events. This paper provides a comprehensive review of Corporate Social Responsibility (CSR) practices employed in the United States and Africa to enhance sustainable resilience in the face of climate risks within the petroleum industry. In the United States, where stringent environmental regulations and public scrutiny prevail, petroleum companies have adopted a range of CSR practices to assess and mitigate climate risks. These practices encompass comprehensive environmental impact assessments, carbon footprint reduction initiatives, and the integration of renewable energy sources into their operations. The paper explores how these CSR practices contribute to the overall resilience of petroleum operations in the United States. In contrast, Africa presents a diverse landscape with varying levels of regulatory frameworks and industrial practices. The paper delves into the unique challenges and opportunities faced by petroleum operations on the African continent in managing climate risks. It highlights the role of CSR practices in promoting sustainable development, community engagement, and ecosystem conservation as integral components of climate risk resilience. The review emphasizes the importance of a holistic approach to climate risk assessment, considering both the environmental and social dimensions of petroleum operations. It sheds light on the need for collaboration between industry stakeholders, governments, and local communities to develop effective CSR strategies that enhance resilience while fostering sustainable practices. By synthesizing insights from both the United States and Africa, this paper contributes to the global discourse on climate risk management in the petroleum industry. It underscores the significance of CSR practices as instrumental tools for achieving sustainable resilience and fostering a harmonious coexistence between petroleum operations and the environment in diverse geopolitical contexts.

Maritime boundaries in the energy transition: carbon dioxide (CO2) storage across maritime jurisdictions

Governments around the world are looking to ensure their transition to full low-carbon economies whilst tackling climate change by implementing offshore carbon capture and storage (CCS) – a method of permanently removing carbon dioxide (CO2) from the burning of fossil fuels and burying it deep below the seabed in suitable geological formations. Among the main targets of such geological formations are depleted, or nearly depleted, offshore oil and gas reservoirs within existing oil-producing fields. However, such reservoirs will frequently transcend maritime boundaries and jurisdictions, ie a shared geological formation could be used on both sides of the maritime boundary for CO2 sequestration and storage. This raises the potential for disputes among nations, transboundary environmental degradation, and business disruption. The paper discusses the role of CCS in the low-carbon energy transition, focusing specifically on international legal aspects related to the storage of CO2 in sub-seabed geological formations of the continental shelf. Ongoing CO2 storage projects are examined to showcase critical technical aspects, including reservoir selection, well design, and post-injection monitoring. The analysis highlights the need for international coordination in situations where CO2 storage occurs across an international boundary and the importance of consent from all states with jurisdiction over the relevant CO2 storage formations. The paper concludes that existing maritime boundary agreements, including those with straddling deposit clauses, are unlikely to cover transboundary CO2 storage operations, except if they are considered incidental to ongoing petroleum operations.

Assessment of occupational external radiation exposure of workers in the Southwest of Libya using portable NaI detector

In this study, gamma dose rates generated from the naturally occurring radioactive materials (NORM) were measured in the waste streams of a large scale and sludge onshore petroleum operations. Measurements conducted in this work involved: sludge recovery from separation tanks, sludge forming, NORM storage, scaling in oil tubulars, scaling in gas production and sedimentation in produced water evaporation ponds. Field work was carried out in many places of different terrain of an operation oil exploration and production in Murzuq basin in the Southwest of Libya. The radiation dose rates were measured using portable InSpector-1000. A total of 400 dose rates were acquired. The highest dose rate was 70 μSv/h acquired in sludge stored in barrels. The estimated mean annual equivalent doses in this field were in the range of 0.2–2.8 mSv/y in the first scenario, while in the second scenario the calculated mean annual equivalent doses were in the range of 0.04–0.68 mSv/y. It is assumed that workers may face various exposures in the field where measurements took place, considering the total annual effective dose to be 1.53 mSv/y. The main radioisotopes detected in these samples indicated by the display of the measuring device were 226Ra and 228Ra but detecting both radioisotopes in the same run is not achievable by using the display of the screen.

CLIMATE RISK ASSESSMENT IN PETROLEUM OPERATIONS: A REVIEW OF CSR PRACTICES FOR SUSTAINABLE RESILIENCE IN THE UNITED STATES AND AFRICA

Climate risk assessment has emerged as a critical component in the sustainability efforts of petroleum operations, given the increasing frequency and severity of climate-related events. This paper provides a comprehensive review of Corporate Social Responsibility (CSR) practices employed in the United States and Africa to enhance sustainable resilience in the face of climate risks within the petroleum industry. In the United States, where stringent environmental regulations and public scrutiny prevail, petroleum companies have adopted a range of CSR practices to assess and mitigate climate risks. These practices encompass comprehensive environmental impact assessments, carbon footprint reduction initiatives, and the integration of renewable energy sources into their operations. The paper explores how these CSR practices contribute to the overall resilience of petroleum operations in the United States. In contrast, Africa presents a diverse landscape with varying levels of regulatory frameworks and industrial practices. The paper delves into the unique challenges and opportunities faced by petroleum operations on the African continent in managing climate risks. It highlights the role of CSR practices in promoting sustainable development, community engagement, and ecosystem conservation as integral components of climate risk resilience. The review emphasizes the importance of a holistic approach to climate risk assessment, considering both the environmental and social dimensions of petroleum operations. It sheds light on the need for collaboration between industry stakeholders, governments, and local communities to develop effective CSR strategies that enhance resilience while fostering sustainable practices. By synthesizing insights from both the United States and Africa, this paper contributes to the global discourse on climate risk management in the petroleum industry. It underscores the significance of CSR practices as instrumental tools for achieving sustainable resilience and fostering a harmonious coexistence between petroleum operations and the environment in diverse geopolitical contexts.
 Keywords: Climate Risk, Risk Assessment, Petroleum, CSR, USA, Africa, Review.

Artificial Intelligence (AI) Application in Process Safety Cumulative Risk Visualization for Petroleum Operations: Conceptual Framework

One of the key challenges in preventing major process safety accidents in an operating plant is the lack of an integrated system/model that brings together the risks posed by the deficiencies / deviations on the safety critical barriers, for operational decision making. Based on this context, a model/framework was developed for assessing and visualizing the accumulation of process safety risks arising from safety critical barriers impairments in petroleum facilities in Niger-Delta Nigeria. Based on the review of the model, the need for an intelligent web-based software was identified. An exploratory study was therefore undertaken through extensive literature review and focused group participants, to develop a conceptual framework for an intelligent web-based software for process safety cumulative risk visualization. The results from the study make it evident that the conceptual framework provides a novel approach in developing an intelligent web-based software using artificial intelligence (AI) techniques, for real time visualization of process safety cumulative risk picture.

Petroleum sludge formation and its treatment methodologies: a review.

Different petroleum operations produce huge amount of oil sludge annually. For instance, US EPA estimates the annual sludge production of each US refinery of 30,000 tons, while the average oily sludge produced from petrochemical industries in China is estimated about 3 million tons per year. In the last year, our center could recover about 30,206 barrels of raw oil from 32,786 barrels of tank bottom sludge (TBS) for different petroleum companies. This sludge causes huge economic losses besides its negative environmental impacts. The accumulation of sludge in the tanks results in reducing the tanks' capacity for storing liquid crude, accelerating the corrosion of the tanks, delay in the production schedule, and disturbing the whole production operation. There are diverse treatment methodologies such as solvent treatment, addition of certain chemicals, and centrifuging. Of course, the environmental regulations and the overall cost limitations are very important in deciding the preferred applicable method(s). Although several works handled the problem of sludge deposition and treatment from different aspects, we intend to introduce a different work. First, composition, formation, types, and properties of TBS were reviewed. Then, environmental and economic problems caused by TBS were revised. At last, different methodologies applied for treatment of oily TBS to recover oil and safe disposal of hazardous remains were investigated focusing on the most straightforward and environmentally friendly protocols. It is expected that this review attracts the experts in petroleum chemistry, and other relevant fields and provides a comprehensive understanding of current sludge control and treatment research.

Alternative Business Model of CCS Projects Unlocks High-CO2 Fields

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 214359, “Business Model of Carbon Capture and Storage (CCS) Projects for High-CO2 Fields,” by Hasnor Lot, SPE, Andrew Yeow, SPE, and Anuar Buang Mahmood, SPE, Petronas, et al. The paper has not been peer reviewed. _ High-CO2 gas fields present a problem to host governments wanting to both ensure security of supply and achieve net-zero aspirations. While carbon capture and storage (CCS) technology holds the promise of technical feasibility to unlock these fields, its commercial success ultimately hinges on the choice of an appropriate business model. This study compares the economics of the traditional business model [i.e., CCS as part of the upstream petroleum operation dedicated to a production sharing contract (PSC)] vs. the alternative business model [i.e., a regional CCS hub separately managed by a special-purpose vehicle (SPV)]. For simplicity, this paper uses the term CCS throughout, although the discussions apply equally well to carbon capture, usage, and storage projects. Background Gas Value Chain and the Cost of Gas (COG). With its higher development, transportation, and processing costs; longer and flatter production profile; and needs for network infrastructure, the economics of gas development is often less robust than that of oil. Therefore, gas development requires not only the establishment of long-term contracts and a complex value chain but also active government support in the form of friendly fiscal and tax regimes and a fair gas-pricing policy. In addition to its role as the upstream regulator, a national oil company (NOC) may also participate in the gas market as an aggregator. Effectively, the NOC signs an upstream gas-sales agreement (UGSA) with upstream contractors committing to buy gas at a volume and price palatable to them. The aggregator then sells the gas it now owns to downstream users. The margin between the buying and selling prices makes up the aggregator’s profit. In return, the aggregator takes on the intermediary roles of matching supply to demand, coordinating fair nomination and curtailment mechanisms, and ensuring that the gas chain as a whole is flexibly robust against operational disruptions. An NOC enjoys the dual roles of operating as a national corporation and acting as the upstream regulator. In its regulatory role, the NOC is cognizant of the need to allocate the risks and rewards of a CCS investment in a fair and efficient manner between participating parties. The business model must improve the overall economic return for both the upstream contractor and the SPV while enhancing the NOC’s integrated value. The business model so designed must also achieve the NOC’s longer-term goal of unlocking resource opportunities and monetizing stranded gas fields.

Significance of organo-mineralogical constituents on pore distribution, fractals and gas sorption mechanism of Permian shale beds in Korba sub-basin of the Son-Mahanadi Valley, India

In this study, shale samples obtained from the Korbasub-basin of Central India have been evaluated for the significance of organo-inorganic constituents in terms of their source potential of gas genesis, pore-matrix setup, and gas adsorption and desorption. The samples were analysed for various properties, such as megascopic features, lithological variations, depositional facies, and sources of organic and inorganic sediments. Also, maceral content, mineralogical constituents, kerogen type, pore distribution, pore structure, fractal characteristics and gas storage capacity were examined. The analysis revealed a trend of alternating bands of carbonaceous matter, silts, intercalations, and fluvial bedding lithofacies patterns indicating that the sediments were deposited under fluvio-terrestrial-lacustrine depositional conditions. Ternary facies analysis of maceral composition and van Krevelen diagram suggested the evolutionary path of type IV kerogen and are thermally matured source material located within the dry hydrocarbon generation window. Evaluation of pore types and pore structures using BET sorption plots (hysteresis H3 and isotherm type IV) revealed the presence of cylindrical, slit and combined cylindrical-slit pores with two distinct fractal characteristics. The discrete macerals underwent partial decomposition during transportation and mixing with inorganic components (clay and minerals), which influenced organic matter preservation, gas genesis, pore fractals and storage mechanism. The chemical index of alteration (CIA – 88.36 to 91.97), weathering (CIW – 96.60 to 98.80) and compositional variation (ICV – 0.31 to 0.70) demonstrated the influence of partial decomposition and strong weathering patterns on the organo-inorganic matter. A significant correlation was observed between pore fractals and elemental composition, particularly related to the resistance of weathering elements such as MgO, Al2O3, Fe2O3, SiO2, P2O5, TiO2, etc., which partially contributed to the formation of pore rugged surfaces. Microscopic and XRD analyses were employed to determine the mineral type, grain shape and size, and their amount leading to the development of the shales brittleness index (MBI). The importance of brittle characteristics, governed by minerals and clays within the shale, is discussed in relation to the hydro-fracturing technique for permeability enhancement. The results of high-pressure methane sorption indicated a moderate gas storage potential. The variation in sorption capacity (VL – 6.65 to 8.25 cc/g) is described through relationships with the ICV, pore diameter, pore volume, liptinite and total maceral content. Fractal dimensions D1 (2.4571–2.5611) and D2 (2.5804–2.7529) exhibited a direct relationship with adsorption properties, indicating the presence of rugged surfaces associated with meso- and macro-scale pores, which primarily control gas storage in shale. This research offers detailed insights into shale gas, providing valuable information for CBM and petroleum operators engaged in methane gas exploration and production. While commercial CBM production has been ongoing in India for over a decade, the exploration and understanding of shale gas reservoir characteristics are still in progress. This investigation adds significant value and highlights the extensive opportunities for research and potentially commercially recovering shale gas in the Korba sub-basin.

Development of complex patterns of anthropogenic uplift and subsidence in the Delaware Basin of West Texas and southeast New Mexico, USA

The Delaware Basin in west Texas and southeast New Mexico is now the largest global oil producing basin, averaging ∼400,000 m3 (∼2,500,000 barrels) per day in 2022. The shale-dominated strata targeted for production can co-produce 4–5 times more water than oil, necessitating disposal by injection of ∼1,400,000 m3 (∼8,700,000 barrels) of water per day in 2022. Through a comprehensive assimilation of regional Sentinel-1 satellite radar data and analysis of production and injection, we show how petroleum operations have caused the development of complex and accelerating patterns of surface deformation from 2015 through 2021. We observe uplift from reservoir swelling, subsidence from reservoir contraction, and the development of linear features that are indicative of faulting. Subsidence is predominantly caused by production, and an important finding of this study is that the magnitude of subsidence is linearly proportional to total production. Uplift is caused by pressurization from wastewater injection of shallow permeable strata. The patterns of uplift are complex and extend laterally well-beyond areas where injection was performed. Linear surface deformation features are observed throughout the Delaware Basin, and they are lengthening and densifying as uplift and subsidence accelerate. Many of the lineations can be linked to known strata-bounded faults and shallow seismicity in the southern Delaware Basin where they serve as permeable and anisotropic conduits for pore pressure migration. In the Northern Delaware Basin, co-seismic rupture is hosted along basement-rooted faults that may link to the linear surface features. Understanding these dynamic changes in Delaware Basin is a pressing concern for management of subsurface reservoirs and safeguarding the surface environment. Concerns include ongoing induced seismicity, hazard of drilling through over-pressured strata, maintenance of integrity for newer wellbores, mitigation of flows of brine and petroleum fluids at the surface of old wellbores, and management of the pore space resource for wastewater injection.

Sustainable Decommissioning in Ghana: Historical Developments, Current Practice and Challenges

When Ghana enacted its first piece of legislation dealing specifically with petroleum operations in the upstream industry in 1984 - the Petroleum (Exploration and Production) Act, 1984 (PNDCL 84) - there was only one provision in the Act which dealt directly with decommissioning. This paper takes an introspective look at developments over time in putting in place an effective and sustainable decommissioning framework for Ghana’s upstream petroleum industry. It analyses the gaps therein and traces attempts over time such as a review by the Commonwealth Secretariat of existing statute, and proposals for a decommissioning scheme, to close them. It analyses measures by the government and encapsulated in statute to fill those gaps and ensure an efficient and sustainable framework. It analyses these developments through to the present when the Saltpond Field is to be decommissioned - Ghana’s first decommissioning exercise. Analysing the practical challenges in decommissioning the Field, impacts and risks, and that of Ghana’s upstream industry in general, the paper concludes that Ghana has through myriad measures strived to ensure that its framework is sustainable and situations such as the current one for instance where it is the government - and not the contractor - paying for decommissioning is averted.

Technology Focus: Gas Production (August 2023)

The demand for natural gas remains unabated and with it the need to further develop and disseminate gas-production-related expertise. A few of the common themes that emerge from recent SPE publications are elaborated upon here. The recovery of condensate from gas condensate depletion drive reservoirs is much lower than the recovery of gas from the same reservoirs because of condensate dropping out below dewpoint pressure. Besides pressure maintenance, no field-proven methods are yet available to mobilize this trapped condensate. Most papers present model or laboratory results without mentioning field data. The same applies to inflow impairment because of condensate dropout; many modeling studies lack validation against field data. Case in point: Pressure/volume/temperature testing generally does not venture below 500–1,000 psi pressure while many reservoirs reach (near-wellbore) pressures well below that range. Reducing emissions of natural gas or CO2 has become a key deliverable of most projects. Some papers present dedicated technology, while many others emphasize emission reduction as an important side benefit. Artificial intelligence (AI) is permeating the exploration and production business, as it does society at large, and features in many recent papers. So far, most applications use advanced data analysis to achieve higher derived data accuracy. This appears to be very successful as long as the evaluated data is within the domain of the training data. It is not always clear how well the AI models perform outside of their training domain. A relevant question is whether complex AI techniques applicable within a restricted domain can or should be used to replace simple, well-established engineering relations. Time will tell how deep and wide AI will affect day-to-day gas production applications. Recommended additional reading at OnePetro: www.onepetro.org. SPE 210136 The Reversible Relationship Between Choke Management and Liquid Yield Trends in Shale Reservoirs by Yalda Barzin, Repsol, et al. SPE 210099 Innovative, Cost-Effective, and Zero-Flaring Solution to Clean Up and Start Up New Wells in a High-H2S Field in Kazakhstan— The Vital Step Forward Toward Net-Zero Carbon Footprint by Timur Tankiyev, Karachaganak Petroleum Operating, et al. SPE 209745 A Data-Driven Approach To Predict the Critical Gas Flow Rate in Gas Wells by Ehsan Rahmati, Ambyint, et al.

Reducing the risk of gas leaks into the ocean floor induced by offshore production well failure

Considering the high number of wells in offshore formations such as the Gulf of Mexico having a risk of leaking gas into the surrounding formations, a deep understanding of the fate and transport of gas released from damaged wells is of special relevance for hazard assessment and prevention in offshore petroleum operations. This work explores a robust strategy to reduce the risk and impact of contaminant releases in an offshore formation by analyzing the applicability of machine learning technology as a tool to forecast the information regarding a possible broaching in a loss of containment scenario of an offshore well. Numerical simulations to describe the system behavior in hydrate-bearing media were implemented to generate the data regarding the broaching day and location, and the hydrate mass generated and the total released CH4 in gas phase in the system. Using the data generated from the different scenarios, we trained multiple Artificial Neural Networks for the prediction of the different outputs, which showed excellent correlations between the input and output features. This is the first study to combine machine learning technology for advanced reservoir simulation to reduce the broaching hazard of gas escaping from an offshore production well.

Assessment of Factors Influencing Process Safety Risk Accumulation in Petroleum Operations in Nigeria

A cross-sectional exploratory assessment of the factors that influence process safety cumulative risk for accident prevention in petroleum operations in Niger-Delta Nigeria was investigated. For the study, a purposive cum random sampling technique was deployed among selected petroleum companies operating in Niger-Delta, Nigeria. A population of 261 of asset integrity engineers/operators, process safety experts, production safety professionals in the petroleum industry in the Niger Delta were sampled using survey questionnaires. Descriptive and inferential statistics (analysis of variance) were used for data analysis. Overall, the study established that process safety cumulative risk assessment has a significant influence in major accident prevention in petroleum operations in Niger-Delta, Nigeria. The study identified seven influencing factors that need to be considered by petroleum industries in Niger-Delta Nigeria, in assessing process safety cumulative risk: (a) preventive and corrective maintenance deviations (agreed by 100% of the respondents), (b) temporary changes (agreed by 98% of the respondents), (c) inhibits/overrides (agreed by 96% of the respondents. Also (d) 97% accounted for downgraded integrity items and (e) 100% accounted for permit to work as influencing factors. The study further showed that (f) simultaneous operations (averred by 99% of the respondents) and (g) open actions from safety review /audits (averred by 92% of the respondents) were the other influencing factors. Including these influencing factors in process safety cumulative risk assessment by the petroleum industries in the study area, will enable better operational decision making in reducing the risk of major accidents.

Petro-States’ Shaping of International Law

Abstract This article highlights the marks left on international law by Iran’s and Algeria’s early, and mid-20th century paths to re-claiming sovereignty over their petroleum reserves. It shows that Iran has significantly affected the contractual model of petroleum operations, whereas Algeria has championed the international law turn of third world internationalism. It thus hopes to shift attention from the frequently cited non-consequentialism of key moments in Third World Internationalism, such as Bandung and the NIEO to the significance of these domestic and transnational processes. While so doing, it is careful to point to the extraordinary bargaining power given to petro-states by the fossil-fuel dependent global economy, which elevated their influence in global affairs over that of other states in the Global South.

Modelling of liquid loading in gas wells using a software-based approach

Liquid loading is the most common operational problem influencing gas well productivity for the petroleum operator. Liquid loading is defined as an operational constraint that is associated with gas wells where the major driving mechanism for hydrocarbon production is by the associated gas-driven mechanisms. Liquid loading occurs when liquid accumulated in the tubing or casing results in the gas velocity lower than the critical value (the minimum velocity required for gas to push the liquid out of the gas well), which overtime leads to a hydrostatic back pressure greater than the formation pressure of the well, thereby limiting the flow of gas into the well. The continuous build-up of pressure from liquid loading eventually minimizes well productivity and expensive work over operations. However, current mathematical models to predict liquid loading are flawed with varying inaccuracies and depending on the models deployed will ultimately lead to loss of production time and well productivity. In our work we present prediction of liquid loading using a software-based model incorporating the particle swarm optimization algorithm, genetic algorithm, and artificial neural network and Bayesian neural network algorithms applications. The results of our research findings show that artificial neural network software-based model with a simulated accuracy of 93% and 92% for test and trained data, respectively, outperformed the particle swarm optimization data-driven model with a simulated sensitivity accuracy of 92% and 83%, and genetic algorithm data-driven models with a simulated accuracy of 89% and 83%. The Bayesian neural network was postulated as a robust model because of its simplicity shown to have simulated accuracy of 77% and 73% for train and test data, respectively. Thus software-based code environment and data-driven model developed and presented in this paper may resolve many of current deficiencies and gaps in the current technical literature to predict liquid loading with high precision offering saving in millions of dollars to the operators.