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Collaborating Authors
Results
Preliminary Assessment of CO2 Storage Potential in the H-59 Block in Jilin Oilfield CCS Project
Zhang, Liang (China University of Petroleum (Huadong)) | Li, X. (China University of Petroleum (Huadong)) | Ren, B. (University of Texas at Austin) | Cui, G. D. (China University of Petroleum (Huadong)) | Ren, S. R. (China University of Petroleum (Huadong)) | Chen, G. L. (PetroChina)
The block H-59 in the Daqingzijing region was selected as a pilot site for the first stage of the CCS project in Jilin oilfield after an extensive assessment. This block is a light oil reservoir with a low permeability. The performance of water flooding after the primary oil recovery was very poor. Therefore, CO2 injection has been started since April 2008 for EOR associated with CO2 storage for environmental benefits. This paper is aimed at assessing the current CO2 storage capacity and distribution at different states in the oil reservoir after 6-year injection until April 2014. Based on various CO2 trapping mechanisms, an evaluation method of CO2 storage potential is established to calculate the theoretical and effective CO2 storage capacities in target oil reservoir the current amount of CO2 buried in the H-59 block was calculated according to the field data. The reservoir numerical simulation was used to analyze the distribution and existing state of CO2 underground. The assessment results show that the theoretical capacity of CO2 storage in the H-59 block is 72.32×104 t, and the effective capacity of CO2 storage is 26.37×104 t. The calculation of effective CO2 storage capacity in oil reservoir considers the engineering practice of field operation during project life. The coverage factor of well pattern (k1) and the sweep coefficient of CO2 within the well pattern (k2) have been introduced in the method. Meanwhile, the mineral trapping was neglected for short-term storage of CO2 based on a preliminary geochemical simulation analysis. There are 17.45×104 t CO2 which has been buried in the block until April 2014. The distribution of buried CO2 between the injection and production wells is mainly determined by the reservoir physical properties and the total amount of CO2 injected in each well. Reservoir simulations indicate that 61.0% of CO2 buried in the oil reservoir has been trapped at supercritical state, and the amounts of CO2 dissolved in oil and water account for 24.4% and 14.6% respectively. These proportions of CO2 at different states are very close to the calculation results of effective CO2 storage capacity. In comparison to the effective CO2 storage capacity, it is thought that the block H-59 still has a certain storage potential of 8.92×104 t at present. For the assessment methods, the parameters k1 and k2 for calculation of effective CO2 storage capacity deserve for further discussion. It should be also noted that the accuracy of CO2 distribution predicted by reservoir simulation greatly depends on the accuracy of geological model. It needs more efforts to improve the understanding of the target reservoir properties.
- North America > United States (1.00)
- Asia > China > Jilin Province (0.85)
- Geology > Geological Subdiscipline (1.00)
- Geology > Mineral > Silicate > Phyllosilicate (0.47)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Europe > Norway > Barents Sea > Hammerfest Basin > License 100 > Block 7121/7 > Snøhvit Field > Stø Formation (0.99)
- Europe > Norway > Barents Sea > Hammerfest Basin > License 100 > Block 7121/7 > Snøhvit Field > Nordmela Formation (0.99)
- Europe > Norway > Barents Sea > Hammerfest Basin > License 100 > Block 7121/5 > Snøhvit Field > Stø Formation (0.99)
- (33 more...)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- (2 more...)
Large Volume of CO2 Injection at the Cranfield, Early Field Test of the SECARB Phase III: Near-Surface Monitoring
Yang, Changbing (U. of Texas at Austin) | Romanak, Katherine D. (U. of Texas at Austin) | Holt, Robert M. | Lindner, Jeff (Mississippi State U.) | Smith, Laura | Trevino, Ramon (Bureau of Economic Geology) | Roecker, Frank | Xia, Yunjui | Rickerts, Jamie | Hovorka, Susan (Bureau of Economic Geology)
Abstract The early field project of the Southeast Regional Carbon Sequestration Partnership (SECARB) was conducted in Cranfield Field, western Mississippi. Injection was into coarse grained fluvial deposits of the Cretaceous lower Tuscaloosa formation forming a gentle anticline at depths of 3300 m. CO2 injection started in July 2008, growing to ~23 wells with total injection rates greater than one million tons/year. Focused monitoring programs of deep subsurface and near-surface have been implemented at different study areas. Here we present results of the near-surface monitoring program over a 3-year period including shallow groundwater monitoring and soil-gas monitoring. A general methodology for detecting CO2 leakage into shallow groundwater chemistry is proposed. A set of geochemical indicator parameters can be identified based on characterization of groundwater geochemistry over the monitoring area and then further tested and validated with numerical modeling approaches, lab experiments and field experiments. For the soil-gas monitoring, a site (P-site) where there are a plugged & abandoned well, a nearby open pit, and an engineered pad, representing a typical near-surface environment for soil monitoring, was selected for detail study. The site was heavily instrumented with different sensors for measuring soil-gas concentrations at different depths, soil water content, matric potential, and weather information. Three monitoring technologies were assessed: soil CO2 concentration measurements alone, CO2 flux measurements on the land surface, and soil-gas component measurements. The results indicate that soil-gas component measurements provide more reliable information for gas leakage detection. The methodologies of near-surface monitoring developed in this study can be used to improve monitoring CO2 leakage at other carbon dioxide sequestration projects. This early field project is funded by the US Department of Energy, National Energy Technology Laboratory as part of the Regional Carbon Sequestration Partnerships program. SECARB is led by Southern States Energy Board. 1. Introduction The Southeast Regional Carbon Sequestration (SECARB) partnership is one of seven Regional Carbon Sequestration Partnerships (RCSP) across the United States and portions of Canada The US Department of Energy, began a 10-year phase III program which includes two large volume injection projects in the lower Tuscaloosa Formation, a formation representative of the Gulf Coast wedge: the early test and an anthropogenic test (Hovorka et al., 2011; Litynski et al., 2009; Rodosta et al., 2011). The "Early Test" began in July 2008, led by the Bureau of Economic Geology and linked to a new CO2-EOR project conducted by Denbury Onshore LLC at Cranfield Field in western Mississippi. The Cranfield site is about 15 miles east to Natchez, MS. Tuscaloosa oil and gas production at Cranfield began in 1944 with drilling of wells in the oil rim below a large gas cap at the top of the structure (Mississippi Oil and Gas Board, 1966). By 1966, nearly all the wells were plugged and abandoned and the Tuscaloosa reservoir was idle and in pressure recovery until Denbury began injection for the EOR project.
- North America > United States > Mississippi > Adams County (0.68)
- North America > United States > Mississippi > Franklin County (0.68)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Sedimentary Geology > Depositional Environment > Continental Environment > Fluvial Environment (0.54)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)