Unconventional Shale Gas-Condensate Reservoir Performance: Impact of Rock, Fluid, and Rock-Fluid Properties and their Variations

Orangi, Abdollah; Nagarajan, Narayana Rao

doi:10.2118/178661-ms

Cited by 3 publications

(3 citation statements)

References 15 publications

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“…However, the actual relative permeability curve could change significantly with large pressure depletion, particularly for very rich gas condensates (Orangi and Nagarajan 2015). This change in relative permeability is due to the changing interfacial tension within the fluid as the heavier ends condense into a liquid phase.…”

Section: Special Core Analysis (Scal) Datamentioning

confidence: 99%

“…Condensate banking is triggered when the pressure falls below the saturation pressure. This is a critical issue in low-permeability reservoirs because this can impair the productivity of the wells through formation damage by reducing the effective permeability around the wellbore (Orangi and Nagarajan 2015). One of the biggest challenges in dealing with condensate banking in tight reservoirs is that the flow of gas occurs at the fracture, but as the pressure depletes, the condensate bank occurs within the fracture, critically damaging the well (Deng et al 2013).…”

Section: Introductionmentioning

confidence: 99%

“…Numerical reservoir simulation is the preferred tool because the reservoir flow problem depends on many pressure-dependent parameters that can affect both the fluid behavior and rock fluid interactions. Numerical solution techniques provide relatively accurate solutions given the correct input data (Aybar et al 2014;Giamminonni et al 2010;Orangi and Nagarajan 2015).…”

Section: Introductionmentioning

confidence: 99%

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Well Placement Optimization in a Gas Condensate Reservoir to Prevent Condensate Banking

Evans

Ghalambor

Orangi

2016

SPE International Conference and Exhibition on Formation Damage Control

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Horizontal wells with multistage hydraulic fractures have become the most common practice to obtain viable commercial production from shale and tight gas reservoirs. With a marked increase of gas production emerging from these tight reservoirs, it is necessary to further study the effects of formation damage due to condensate dropout and how best to prevent and mitigate this damage. There are two common ways to mitigate and treat condensate banking. The first method is to fracture the existing well. This allows bypassing the condensate and therefore increasing well productivity. The second method is to shut-in the well and allow pressure to build up so that the dropped out liquids are revaporized back into the gas. These options, respectively, involve large capital expenses and temporary decrease of production. Before deploying these solutions, the condensate dropout damage can be strongly reduced at no (field) cost by optimizing the well location.This objective in this study was to determine the optimum well location to mitigate formation damage due to condensate dropout in a tight gas well. Compositional reservoir simulations were conducted with different condensate gas ratios and relative permeability curves to quantify the loss of productivity due to formation damage under different conditions. The target formation was 100 ft thick, and a tartan grid was used to represent the hydraulic fractures within the tight gas well.This study determined that well placement plays a key role in preventing damage due to condensate banking. The optimized placement of the well can drastically enhance the viability of a project by allowing for a larger recovery.

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Section: Special Core Analysis (Scal) Datamentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Well Placement Optimization in a Gas Condensate Reservoir to Prevent Condensate Banking

Evans

Ghalambor

Orangi

2016

SPE International Conference and Exhibition on Formation Damage Control

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Sensitivity analysis and economic optimization studies of inverted five-spot gas cycling in gas condensate reservoir

Shams

Zhang

et al. 2017

Open Physics

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Gas condensate reservoirs usually exhibit complex flow behaviors because of propagation response of pressure drop from the wellbore into the reservoir. When reservoir pressure drops below the dew point in two phase flow of gas and condensate, the accumulation of large condensate amount occurs in the gas condensate reservoirs. Usually, the saturation of condensate accumulation in volumetric gas condensate reservoirs is lower than the critical condensate saturation that causes trapping of large amount of condensate in reservoir pores. Trapped condensate often is lost due to condensate accumulationcondensate blockage courtesy of high molecular weight, heavy condensate residue. Recovering lost condensate most economically and optimally has always been a challenging goal. Thus, gas cycling is applied to alleviate such a drastic loss in resources. In gas injection, the flooding pattern, injection timing and injection duration are key parameters to study an efficient EOR scenario in order to recover lost condensate. This work contains sensitivity analysis on different parameters to generate an accurate investigation about the effects on performance of different injection scenarios in homogeneous gas condensate system. In this paper, starting time of gas cycling and injection period are the parameters used to influence condensate recovery of a five-spot well pattern which has an injection pressure constraint of 3000 psi and production wells are constraint at 500 psi min. BHP. Starting injection times of 1 month, 4 months and 9 months after natural depletion areapplied in the first study. The second study is conducted by varying injection duration. Three durations are selected: 100 days, 400 days and 900 days. In miscible gas injection, miscibility and vaporization of condensate by injected gas is more efficient mechanism for condensate recovery. From this study, it is proven that the application of gas cycling on five-spot well pattern greatly enhances condensate recovery preventing financial, economic and resource loss that previously occurred.

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CO2 Injection to Mitigate Condensate Banking in a Low-Permeability Reservoir

Evans

Ghalambor

Orangi

2016

SPE International Conference and Exhibition on Formation Damage Control

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One of the main challenges of producing tight or low-permeability gas reservoirs is condensate banking when production starts as the reservoir pressure drops below the dewpoint pressure. Condensate banking causes formation damage and subsequently damages production. The normal procedure to mitigate condensate banking is to hydraulically fracture the well to bypass the condensate bank and improve production from that well. Modeling the condensate banking along the hydraulic fracture is critical to understanding the loss of productivity.We investigated the feasibility of simulating a cyclic CO 2 injection scheme to mitigate formation damage due to gas condensate dropout in a low-permeability gas reservoir. The field was modeled using a tartan grid to be able to model the hydraulic fracture explicitly. In addition to the hydraulic fracture, the study examined how much of a role the condensate-gas ratio (CGR) plays in the condensate banking and how to best position a well in a low-, medium-, and high-CGR fluid. For the mitigation phase, different cyclic parameters such as injection rate, injection pressure, and soaking time for the cyclic CO 2 injection were considered.The study found that the volume of the GCR played a critical role in determining injection rates and pressure to best be able to mitigate damage due to condensate banking.

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Unconventional Shale Gas-Condensate Reservoir Performance: Impact of Rock, Fluid, and Rock-Fluid Properties and their Variations

Cited by 3 publications

References 15 publications

Well Placement Optimization in a Gas Condensate Reservoir to Prevent Condensate Banking

Well Placement Optimization in a Gas Condensate Reservoir to Prevent Condensate Banking

Sensitivity analysis and economic optimization studies of inverted five-spot gas cycling in gas condensate reservoir

CO2 Injection to Mitigate Condensate Banking in a Low-Permeability Reservoir

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