Coupling of Wellbore and Surface Facilities Models with Reservoir Simulation to Optimize Recovery of Liquids from Shale Reservoirs

Fragoso, Alfonso; Trick, Mona D.; Harding, Thomas G.; Selvan, Karthik; Aguilera, Roberto

doi:10.2118/185079-ms

“…Cyclic gas injection or gas huff and puff has been proposed to enhance the oil recovery in tight oil reservoirs [1][2][3][4]. It is implemented through injecting certain type of gas into the multistage hydraulically fractured horizontal well, soaked for some time, and produced back from the same well.…”

Section: Introductionmentioning

confidence: 99%

Conformance Control for Tight Oil Cyclic Gas Injection Using Foam

Wei

¹

,

Zhang

²

,

Yang

³

et al. 2022

Geofluids

0

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Cyclic gas injection has been proven to be an effective enhanced oil recovery (EOR) technique for tight oil reservoirs. During such processes, we expect recovery mechanisms such as oil swelling, oil viscosity reduction, vaporization, and pressure support, which highly relies on the successful conformance control of the injected gas. In this work, we present the numerical simulation study of using foam for improving the conformance control of cyclic gas injection in tight oil reservoir. We focus on improving two categories of conformance control problems using foam, making the injection profile for single well more evenly distributed and mitigating the gas breakthrough to adjacent wells through the connected hydraulic fractures in a multiwell setting. The simulation results show that foam has shown major impact in improving the gas conformance control in both cases. Typical recovery factor improvements are estimated to be up to 1% for lean gas injection in this tight oil reservoir. In conclusion, we have demonstrated the great potential of using foam to improve the conformance in tight oil cyclic gas injection process.

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“…Input parameters for the base reservoir model (modified from[16,17,[19][20][21][22][23][24][25][26]). …”

mentioning

confidence: 99%

Development of Production-Forecasting Model Based on the Characteristics of Production Decline Analysis Using the Reservoir and Hydraulic Fracture Parameters in Montney Shale Gas Reservoir, Canada

Shin

¹

,

Nguyen-Le

²

,

Kim

³

et al. 2021

Geofluids

1

0

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This study developed a production-forecasting model to replace the numerical simulation and the decline curve analysis using reservoir and hydraulic fracture data in Montney shale gas reservoir, Canada. A shale-gas production curve can be generated if some of the decline parameters such as a peak rate, a decline rate, and a decline exponent are properly estimated based on reservoir and hydraulic fracturing parameters. The production-forecasting model was developed to estimate five decline parameters of a modified hyperbolic decline by using significant reservoir and hydraulic fracture parameters which are derived through the simulation experiments designed by design of experiments and statistical analysis: (1) initial peak rate ( P hyp ), (2) hyperbolic decline rate ( D hyp ), (3) hyperbolic decline exponent ( b hyp ), (4) transition time ( T transition ), and (5) exponential decline rate ( D exp ). Total eight reservoir and hydraulic fracture parameters were selected as significant parameters on five decline parameters from the results of multivariate analysis of variance among 11 reservoir and hydraulic fracture parameters. The models based on the significant parameters had high predicted R 2 values on the cumulative production. The validation results on the 1-, 5-, 10-, and 30-year cumulative production data obtained by the simulation showed a good agreement: R 2 > 0.89 . The developed production-forecasting model can be also applied for the history matching. The mean absolute percentage error on history matching was 5.28% and 6.23% for the forecasting model and numerical simulator, respectively. Therefore, the results from this study can be applied to substitute numerical simulations for the shale reservoirs which have similar properties with the Montney shale gas reservoir.

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Material Balance Forecast of Huff-and-Puff Gas Injection in Multiporosity Shale Oil Reservoirs

Orozco

¹

,

Aguilera

²

,

Selvan

³

2018

Day 2 Wed, March 14, 2018

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Primary oil recovery from shales is very low, rarely exceeding 10% of original oil in place (OOIP). The low recovery has aroused a recent and growing interest in the petroleum industry for using Improved Oil Recovery (IOR) methods in shales. This paper presents a new semi-analytical material balance equation (MBE) to forecast the performance of shale oil reservoirs under natural depletion and huff-and-puff gas injection scenarios. For undersaturated reservoirs, recovery is calculated from the proposed MBE explicitly using a multiporosity effective oil compressibility. For saturated reservoirs, the MBE is solved at each pressure step using a finite differences scheme. For huff-and-puff gas injection, the average reservoir pressure p is calculated after injecting a certain gas volume during the huff period. At each huff-and-puff cycle, the remaining OOIP is considered, and the injected gas volume (which is known) is written in terms of the p following injection (which is unknown). Adding the gas injection term to the MBE generates a nonlinear equation for p, which is solved using a numerical method. Results indicate that oil recovery from shales can be increased significantly by huff-and-puff gas injection. A case study from the Eagle Ford shale in the United States is used to demonstrate these results, which are presented in tabular form as well as crossplots of oil rates, cumulative oil production, gas-oil ratio and average reservoir pressure vs. time. An important feature of the proposed MBE is the inclusion of hydraulic fractures, as well as inorganic, organic and natural fracture porosities. These porosities are included in a history-matching presented in detail for a well undergoing huff-and-puff gas injection. The novelty of this work resides on the introduction of a new MBE that considers multiple porosities and enables quick evaluations of primary recovery and huff-and-puff gas injection scenarios in shale oil reservoirs. The new MBE results compare favorably against real data of the Eagle Ford shale. The good comparison allows making reasonable projections of future oil rates and cumulative oil recoveries by huff-and-puff gas injection.

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Coupling of Wellbore and Surface Facilities Models with Reservoir Simulation to Optimize Recovery of Liquids from Shale Reservoirs

Cited by 4 publications

References 20 publications

Conformance Control for Tight Oil Cyclic Gas Injection Using Foam

Conformance Control for Tight Oil Cyclic Gas Injection Using Foam

Development of Production-Forecasting Model Based on the Characteristics of Production Decline Analysis Using the Reservoir and Hydraulic Fracture Parameters in Montney Shale Gas Reservoir, Canada

Material Balance Forecast of Huff-and-Puff Gas Injection in Multiporosity Shale Oil Reservoirs

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