From Sandface to Processing Plant, an Integrated View of an Operating Envelope in a Gas Condensate System

2017 ◽  
Author(s):  
M Sueiro. ◽  
A Lanchimba. ◽  
C Bilbao. ◽  
R Tavara. ◽  
R Canchucaja. ◽  
...  
Keyword(s):  
Gas Condensate ◽  
Processing Plant ◽  
Condensate System

Carbon Dioxide in a Natural Gas-Condensate System

1946 ◽  
Vol 38 (5) ◽  
pp. 530-534 ◽  
Author(s):  
Fred H. Poettmann ◽  
Donald L. Katz
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Gas Condensate ◽  
Condensate System

Effect of salt and water cuts on hydrate anti-agglomeration in a gas condensate system at high pressure

Fuel ◽  
2017 ◽  
Vol 210 ◽  
pp. 713-720 ◽  
Author(s):  
Sanbao Dong ◽  
Mingzhong Li ◽  
Abbas Firoozabadi
Keyword(s):  
High Pressure ◽  
Gas Condensate ◽  
Condensate System

Experimental Determination of Relative Permeabilities for a Rich Gas/Condensate System Using Live Fluid

2009 ◽  
Vol 12 (02) ◽  
pp. 263-269 ◽  
Author(s):  
Jeffrey F. App ◽  
Jon E. Burger
Keyword(s):  
Steady State ◽  
Capillary Number ◽  
Single Phase ◽  
Gas Condensate ◽  
Relative Permeabilities ◽  
State Process ◽  
Reservoir Fluid ◽  
Condensate System ◽  
The Impact ◽  
Model Fluids

Summary Measurement of gas and condensate relative permeabilities typically is performed through steady-state linear coreflood experiments using model fluids. This study addresses experimental measurement of relative permeabilities for a rich-gas/condensate reservoir using a live, single-phase reservoir fluid. Using a live, single-phase reservoir fluid eliminates the difficulties in designing a relatively simple model fluid that replicates the complicated thermodynamic and transport properties of a near-critical fluid. Two-phase-flow tests were performed across a range of pressures and flow rates to simulate reservoir conditions from initial production through depletion. A single-phase multirate experiment was also performed to assess inertial, or non-Darcy, effects. Correlations were developed to represent both the gas and condensate relative permeabilities as a function of capillary number. A nearly 20-fold increase in gas relative permeability was observed from the low- to high-capillary-number flow regime. Compositional simulations were performed to assess the impact of the experimental results for vertical- and horizontal-well geometries. Introduction Well-deliverability estimates for gas/condensate systems require accurate prediction of both gas and condensate effective permeability. This is particularly important within the near-wellbore region where the pressures often fall below dewpoint causing retrograde condensation. Within this region, pressure gradients in both flowing phases are large and the interfacial tension between the gas and condensate is low. This results in relative permeabilities that are rate sensitive. Under these conditions, both capillary number and non-Darcy effects must be considered in modeling of gas/condensate flows. The relative permeabilities increase with increasing capillary number and are reduced by inertial, or non-Darcy, flow effects. Gas and condensate relative permeabilities are typically determined by steady-state linear coreflood experiments. Numerous experimental studies have been performed demonstrating an improvement in both gas and condensate relative permeability at high velocities and at low interfacial tension (Henderson et al. 1998; Henderson et al. 1997; Ali et al. 1997). These studies used model fluids to represent the reservoir fluid, which generally represented leaner gas/condensate systems. Chen et al. (1995) performed similar experiments using a recombined gas/condensate system from a North Sea field. Proper recombination with surface gas and condensate samples, however, assumes that the correct condensate/gas ratio is known. Using single-phase downhole samples obtained at pressures above the dewpoint eliminates this uncertainty. Fevang and Whitson (1996) have shown that krg for a steady state process is a function of the krg/kro ratio, where the krg/kro ratio is a function of pressure. The dependency of krg on both the capillary number (Nc) and the krg/kro ratio for a pseudosteady-state process has been demonstrated experimentally by Whitson et al. (1999) and Mott et al. (1999). These studies used either model fluids or recombined reservoir fluids with krg/kro ratios primarily within the range of 1 to 90. The lower krg/kro ratios represent richer fluids, while the higher krg/kro ratios represent leaner fluids. The fluids studied in this paper, however, are significantly richer, with krg/kro ratios in the range of 0.05 to 0.15 on the basis of fluid compositions at initial reservoir conditions. Non-Darcy or inertial effects reduce relative permeabilities. This has been demonstrated through linear coreflood experiments by several investigators (Lombard et al. 2000; Henderson et al. 2000; Mott et al. 2000). Multirate non-Darcy single-phase experiments were performed as part of this study because of the anticipated high flow rates from this reservoir. The objectives of this study were (1) to experimentally measure gas and condensate relative permeabilities for a rich gas/condensate system using a live, single-phase reservoir fluid; (2) assess the magnitude of inertial effects through the measurement of the non-Darcy coefficient; and (3) evaluate the impact of the capillary-number-dependent relative permeabilities and non-Darcy effects on the performance of vertical and horizontal wells.

scholarly journals Management of injected nitrogen into a gas condensate reservoir

2016 ◽  
Vol 36 (1) ◽  
pp. 52-61 ◽  
Author(s):  
Hadi Belhaj
Keyword(s):  
Gas Condensate ◽  
Abu Dhabi ◽  
Processing Plant ◽  
Peak Shaving ◽  
Gas Streams ◽  
Gas Processing ◽  
The North ◽  
Condensate Reservoir ◽  
Heat Value ◽  
The Impact

<p>This study investigates the means of deferring the breakthrough of injected N2 and alleviating the impact of such on production rates and specifications as well as minimizing the required changes to the gas processing facilities. This aimed at assisting the ongoing efforts to transfer the Cantarell experience to Abu Dhabi, where large amounts of N2 gas will be generated and injected into a large gas condensate reservoir to partially substitute the recycling of lean gas. This will bring forward the opportunity to exploit lean gas by securing base load supplies before the start of reservoir blowdown, compared to the peak shaving approach currently practiced. Managing N2 breakthrough starts by better understanding the pattern at which N2 injection spreads into the gas accumulation. Based on the findings of initial subsurface and plant simulations carried out in 2008, N2 breakthrough in Abu Dhabi might be possibly deferred by segmenting the reservoir into a rich N2 region and lean N2 region. The approach assumes no thief zones will be faced and no channeling of N2 injected between the two regions is taking place. N2 is injected in the north region of the reservoir. The production of that region will be segregated and fed to a gas processing plant of lower NGL (natural gas liquid) recovery, which essentially takes longer time to start suffering the deterioration of residue gas (gas mixture resulted after separating NGL) quality. The residue gas use can be limited to re-injection where the effect of below specification LHV (Low Heat Value) would not be an issue. The rest of the reservoir feeds another gas processing plant of higher NGL recovery level from which an amount of residue gas equivalent to that of the injected N2 will be rerouted to the sales network. This scenario will significantly delay as well as downsize the requirement of a N2 rejection plant. There is technical and certainly economical advantage of deferring the installation of costly N2 rejection units. Such a requirement can be entirely eliminated if the sales gas specification can be relaxed considering blending with other gas streams of higher LHV, and in collaboration with gas customers, i.e. assessing their capability to tolerate feedstock of lower specifications. It must be noted that such school of thinking may not necessarily be eventually embraced. The chosen scenario will also depend on the final configuration, i.e., wells grouping and gas gathering, of the ongoing project.</p>

Studying the impact of carbon dioxide on phase transitions of gas-condensate systems and dispersion of retrograde condensate

2021 ◽  
pp. 17-22
Author(s):  
N.N. Hamidov ◽  
◽  
◽  
Keyword(s):  
Carbon Dioxide ◽  
Phase Transitions ◽  
Gas Phase ◽  
Development Process ◽  
Gas Condensate ◽  
Critical Parameters ◽  
Physico Chemical ◽  
Retrograde Condensation ◽  
Condensate System ◽  
The Impact

The paper studies the effect of carbon dioxide on the phase transitions within gas-condensate systems and defines its role on the evaporation of retrograde condensate isolated in formation due to the decreasing pressure during development process. Based on the experiments carried out by special methodology in рVT bomb, the essence of various impact of carbon dioxide amount in the content of gas-condensate mixture on the physico-chemical and thermo-dynamic parameters of the system depending on the temperature interval revealed. As a result of experiments, it was defined that the increase of carbon dioxide within gas-condensate mixture raises the content of dispersed condensate in gas phase. Moreover, the increase of CO2 in gas phase leads to the growth of gas amount dissolved in a unit volume of condensate as well. It is shown that the effect of carbon dioxide on the pressure of retrograde condensation within gas-condensate system cannot be definitely estimated. The pressure of retrograde condensation within such mixtures may be different in various temperature diapasons due to the change of the features and critical parameters of the system.

Fluid behavior of gas condensate system with water vapor

2017 ◽  
Vol 438 ◽  
pp. 67-75 ◽  
Author(s):  
Zhouhua Wang ◽  
Hanmin Tu ◽  
Ping Guo ◽  
Fanhua Zeng ◽  
Tingyi Sang ◽  
...  
Keyword(s):  
Water Vapor ◽  
Gas Condensate ◽  
Fluid Behavior ◽  
Condensate System
Sign in / Sign up

Export Citation Format

Share Document