Design in the process of controlling and utilizing carbon dioxide in oil and gas well with the technology of carbon capture and storage

Abstract

The utilization of oil and gas is very important in the development activities and tends to increase every year. This has caused oil and gas reserves to decrease and the concentration of carbon dioxide (CO2) to increase in the atmosphere, which can trigger the effects of greenhouse gases and global warming on Earth's surface. One of the technologies that can reduce the CO2 concentration and at the same time increase the gas recovery is the technology of carbon dioxide capture and storage (CCS). It is used to capture CO2 from the combustion process and injected into the reservoir to raise oil and gas reserves. One potential area of Indonesia to implement the CCS technology is West Java, the fifth largest of oil and gas reserves in Indonesia. The objective of this study was to design CO2 capture and storage processes in geology formation, in which the absorption process and enhanced oil recovery (EOR) technology are used in the design of CO2 capture and storage processing. The study was based on a field survey and laboratory analysis of the flaring gas composition, where the design of CO2 capture process was treated with Aspen Plus with the variations of absorber stage number, from 7 until 17, and the variations of some amine solutions such as monoethanolamine (MEA), diisopropanolamine (DIPA), diethanolamine (DEA) and methyldiethanolamine (MDEA) as the absorbent, while the CO2 storage process was treated by screening the well criteria, namely XC-4, XG-1, XG-11, XT-27, and XJ-140, minimum miscibility pressure (MMP) value of well fluid, and computer modelling group (CMG). The most efficient was the process design of CO2 capture at stage 17 in the absorber column with the DEA solution, with the efficiency in CO2 removal (99.54%) and the reduction of CO2 concentration from 39.73% with the flow rate of 33,762 kmol/hr as input to 17.49% with the flow rate of 5,906 kmol/hr as output. The resulted process design showed that 580,585 ton of CO2/year could be processed and 101,565 ton of CO2/year can be reused. The most efficient of CO2 storage process design was with the simulated reservoir in the XJ-140 well as the EOR well and XJ field, with cumulative oil production of 5.08 million metric stock tank barrel (MMstb) from 2011-2030 and with the recovery factor of 9.53%. The resulted estimation of the amount of oil collected and CO2 stored showed that CO2 can be stored into the geological formation, varying from 0.5-1 Mton and the potential additional production of oil was 3.6-7.2 MMstb. The economic analysis found that XJ field is very profitable with the application of EOR with an initial investment of US$ 7,500,000, that is, it can obtain the net present value (NPV) of US$ 247,000, internal rate of return (IRR) of 17.41%, and pay back period (PBP) in 2015, or for 4 years, 4 month, if the project begins in 2011 with the profitability index of 1.01. The revenue from oil is US$ 143,864 for the Regency and US$ 71,932 for the Province, while the revenue from gas is US$ 213,902 for the Regency and US$ 106,951 for the Province. EOR management strategy may be commercialized in a cooperation contract with local enterprises, for example with Pertamina.