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Addressing some tasks in the development of gas deposits on the basis of estimation of their stocks by various methods
Решение некоторых задач разработки газовых месторождений на основе оценки их запасов различными методами
- Gissarneftegaz JV, Uzbekistan
- Tashkent State Technical University, Tashkent, Uzbekistan
- UZ-KOR Gas Chemical JV LLC, Uzbekistan
Highlights
- Mean reservoir temperature: 111.9 °C in the gas pool of horizon XV, 112.6 °C in the middle of horizon XVa.
- Mean geothermal gradient 2.23 °C per 100 m; geothermal step 46.19 m/°C.
- Mean reservoir pressure 32.38–33.04 MPa; anomaly coefficients 1.075–1.113.
- Reservoir pressure fell from 31.7 MPa to 17 MPa, by 53.6%, by 1 January 2015.
- Open porosity 1.9–13.9% (dolomites) and 2.2–8.5% (limestones); permeability 0.01–46.8·10⁻³ µm² and 0.01–0.5·10⁻³ µm².
- Structure 6,400 × 1,700 m along the −2,600 m contour, 190–200 m high.
Keywords
- reservoir temperature
- geothermal gradient
- reservoir pressure
- Upper Jurassic carbonates
- gas condensate
- North Guzar field
Summary
Written about estimating gas reserves, this paper compares volumetric, pressure-decline and statistical estimates for the North Guzar gas-condensate field. About 90% of Uzbekistan’s hydrocarbon production comes from the Bukhara–Khiva region, mostly from its Jurassic carbonate formation.
North Guzar was discovered in 1991. Its productive horizons XV and XVa are Upper Jurassic dolomites and limestones that form one gas reservoir with a common gas–water contact, in a north-east-trending brachyanticline of 6,400 × 1,700 m along the −2,600 m contour and 190–200 m high. Open porosity is 1.9–13.9% in the dolomites and 2.2–8.5% in the limestones; both are fractured-porous reservoirs. Mean reservoir temperature is 111.9 °C in the gas pool of horizon XV and 112.6 °C in the middle of horizon XVa. The mean geothermal gradient is 2.23 °C per 100 m, a geothermal step of 46.19 m/°C.
Mean reservoir pressure is 32.38 MPa in the upper part of the pool, 32.9 MPa in the middle and 33.04 MPa at the gas–water contact, with anomaly coefficients of 1.075–1.113. The field came into production in 2007. Output peaked in 2009 and fell sharply from 2010 as more water entered the wells and reservoir pressure dropped from 31.7 to 17.0 MPa. By 1 January 2015, 13 wells had been drilled and 7 were producing. The pressure-decline method gives 67.33% of the volumetric reserve estimate.
How to cite
A. H. Agzamov, O. G. Khayitov and O. P. Matniyazov (2017). Addressing some tasks in the development of gas deposits on the basis of estimation of their stocks by various methods. O‘zbekiston neft va gaz jurnali (Uzbek Journal of Oil and Gas), No. 4, 2017, pp. 32–35. https://drive.google.com/file/d/10PfmwiVqczax_lLevqMinM6htvt2J8d0/view