Development of Gas-Condensate Reservoirs by Directional Intracontour Waterflooding
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Résumé
Development of Gas-Condensate Reservoirs by Directional Intracontour Waterflooding L. Berman; L. Berman Test Ltd. Search for other works by this author on: This Site Google Scholar V. Ryzhik; V. Ryzhik Technion, Dept. of Civil Engineering, Environmental and Water Resources Engineering Search for other works by this author on: This Site Google Scholar K. Mirotchnik; K. Mirotchnik TIPM Laboratory Search for other works by this author on: This Site Google Scholar K. Allsopp K. Allsopp TIPM Laboratory Search for other works by this author on: This Site Google Scholar Paper presented at the SPE/CERI Gas Technology Symposium, Calgary, Alberta, Canada, April 2000. Paper Number: SPE-59775-MS https://doi.org/10.2118/59775-MS Published: April 03 2000 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Berman, L., Ryzhik, V., Mirotchnik, K., and K. Allsopp. "Development of Gas-Condensate Reservoirs by Directional Intracontour Waterflooding." Paper presented at the SPE/CERI Gas Technology Symposium, Calgary, Alberta, Canada, April 2000. doi: https://doi.org/10.2118/59775-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu nav search search input Search input auto suggest search filter All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Unconventional Resources Conference / Gas Technology Symposium Search Advanced Search AbstractThis paper presents an overview of some of the advanced water-flooding technologies developed for gas-condensate reservoirs (GCR) in the former Soviet Union. Although developed in the 1970's and since then successfully applied in the field, there are no published accounts of this technology being applied elsewhere.This technology is based on both the block structure of most gas-condensate reservoirs and the "block reservoir structure" of major fields. In both case areas of low permeability connect seemingly separate reservoirs or field zones. These areas of low permeability act in a manner similar to semi-permeable membranes. The flow of water through low permeability areas, especially those containing clay deposits, takes place only if the pressure gradient exceeds some initial value (initial gradient). Such phenomenon also occurs for gas flow, but the values of the initial pressure gradient for gas (Gg) are much lower than for water. As a result, injected water cannot flow through these areas of low permeability and move from one highly-permeable zone to another. However, at the same time gas can flow freely from block to block provided the pressure gradient is higher than Ggi. The properties of gas-saturated rocks prevent water invasion into the "dry" blocks, until the blocks with injection wells are almost totally saturated by water (at Sgres). By utilizing this phenomena, greater gas and condensate recoveries can be achieved than by using water injection schemes which disregard the intrinsic heterogeneity of reservoirs.An experimental laboratory program verifying the phenomenon of initial pressure gradient was performed in the TIPM Laboratory in 1999. This work is ongoing.GeneralThe performance of a gas-condensate reservoir is affected by the decline in reservoir pressure (Pf). The smaller the final reservoir pressure (Pff), the greater the total gas recovery efficiency (GRE). After the reservoir pressure has declined below the condensation point (Pdp), retrograde condensation and liquid condensate precipitation commences in the pore spaces. As the reservoir pressure declines, the effective stress (Pef) grows, causing rock deformation and decreasing the permeability and porosity. The negative consequences of this pressure decline are greatest, when the initial content of dissolved condensate in gas (condensate-gas ratio - CGR0) is higher than in the reservoir fluid. It is also related to the initial reservoir pressure (Pfo) value with higher values leading to more serious problems. The negative consequences of reservoir pressure decline are also increased if the reservoir rocks are hydrophobic. The possibility of reservoir rocks becoming hydrophobic is greatest in high-permeable deposits after liquid condensate precipitation has begun; the likelihood of hydrophobicity developing is further increased if residual oil is present in the gas reservoir. Keywords: membrane, breakthrough, gas-condensate reservoir, permeability, gas production, upstream oil & gas, deposit, pressure gradient, reservoir, recovery efficiency Subjects: Improved and Enhanced Recovery, Formation Evaluation & Management, Unconventional and Complex Reservoirs, Waterflooding, Gas-condensate reservoirs This content is only available via PDF. 2000. Society of Petroleum Engineers You can access this article if you purchase or spend a download.
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| Catégorie | Codex | Gemma |
|---|---|---|
| Métarecherche | 0,000 | 0,000 |
| Méta-épidémiologie (sens strict) | 0,000 | 0,000 |
| Méta-épidémiologie (sens large) | 0,000 | 0,000 |
| Bibliométrie | 0,000 | 0,000 |
| Études des sciences et des technologies | 0,000 | 0,000 |
| Communication savante | 0,000 | 0,000 |
| Science ouverte | 0,000 | 0,000 |
| Intégrité de la recherche | 0,000 | 0,000 |
| Charge utile insuffisante (le modèle a refusé de juger) | 0,002 | 0,000 |
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