## 1 Introduction  
Corrosion remains a critical challenge in the oil-and-gas industry, with severe safety, economic, and environmental implications. Global losses due to corrosion are estimated to exceed USD 2.5 trillion annually, representing 3-4% of the global GDP [1]. Oil and natural gas, which account for over 60% of global energy consumption, continue to be indispensable, despite the rise of alternative energy sources [2]. In this context, carbon steel, despite its susceptibility to corrosion, is widely used in oil-and-gas exploration due to its cost-effectiveness and mechanical properties. In China alone, over 3.5 million tons of carbon steel is used annually in the sector [3]. China's unique geological conditions exacerbate corrosion risks, particularly for downhole tubing materials exposed to high-temperature and high-pressure environments and aggressive media such as CO\({}_{2}\), H\({}_{2}\)S, and saline water. Enhanced oil recovery (EOR) techniques like acid fracturing and CO\({}_{2}\) flooding further increase the corrosive challenges by raising the water content and corrosive ion concentrations [4]. The resulting severe corrosion causes mechanical failures, production halts, and billions of dollars in losses annually. Moreover, corrosion-related leaks contribute to greenhouse gas emissions, hindering carbon neutrality efforts [5]. To address these issues, a range of corrosion protection measures have been improved, including material enhancement, coatings, and corrosion inhibitors. Research on corrosion inhibitors has demonstrated their efficacy in mitigating corrosion in oil-and-gas exploration environments [6]. The utilization of corrosion inhibitors is especially noteworthy for its cost-effectiveness, ease of application, and versatility across diverse scenarios. Nevertheless, traditional corrosion inhibitors still encounter significant limitations, such as a short protection period and the lack of responsiveness to the change of corrosive media, which need further investigation. Corrosion inhibitors embedded in solid matrices can be designed to release through various mechanisms, including mechanical deformation or wear, chemical reactions, electromagnetic activation, and thermal response. Among these, temperature responsive release is particularly advantageous in oilfield applications, where temperature fluctuations significantly impact corrosion rates. The ability of GE-EP@OIMs to autonomously regulate its release based on temperature ensures effective protection by accelerating inhibitor release under high-temperature, highly corrosive conditions while maintaining long-term inhibition in moderate conditions. Conventional liquid corrosion inhibitors, although widely employed, possess notable drawbacks, namely, uneven dispersion and a brief protection duration. In production environments, liquid inhibitors frequently fail to form a uniform protective film, resulting in inconsistent corrosion protection. This is especially pronounced in turbulent flow or complex geometric configurations where local inhibitor concentrations vary [7]. Their effectiveness is further curtailed in high-temperature and high-salinity environments, where they degrade rapidly and offer protection for merely a few hours to a few days. Frequent reapplication not only escalates operational costs but also diminishes efficiency [8]. Furthermore, the dependence on external equipment, such as high-pressure injection systems, exacerbates these challenges. These systems are essential for the delivery of liquid inhibitors but entail a high initial investment, continuous maintenance, and substantial energy consumption. This reliance augments operational complexity, particularly in remote or offshore oil fields, and induces inefficiencies, especially during equipment failures, which can precipitate production downtime [9]. Moreover, high-pressure systems struggle to ensure the uniform distribution of inhibitors across extensive pipeline networks, further undermining their effectiveness.