Naturally Fractured Reservoirs and their Link to Tight and Shale Petroleum Reservoirs

Aguilera, Roberto F.

doi:10.2118/199073-ms

Cited by 11 publications

(1 citation statement)

References 50 publications

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“…The main buried depth of the bottom boundary of Wufeng Formation in the working area is 500-2000 m, and the formation dip in the area varies greatly (2° ~ 40°). Under the influence of two groups of compressional and torsional strike-slip faults and one group of compressional faults, local natural fractures developed [5] (Figure . 2).…”

Section: Geological Featurementioning

confidence: 99%

Evaluation on effect of temporary plugging and diverting in operation of shale gas well fracturing based on ultrasonic imaging logging and suggestion on optimization of technological measures

chen,

wang,

chen

et al. 2024

Eighth International Conference on Energy System, Electricity, and Power (ESEP 2023)

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With the application of multi-stage hydraulic fracturing technology in horizontal wells of shale gas, the number of perforating clusters in each section has gradually increased. How to use temporary plugging and diverting technology to improve the opening efficiency of each perforation cluster is crucial to fracturing effect. This paper analyzes the temporary plugging and diverting effect in multi-cluster fracturing by combination of geological characteristics of shallow shale gas in Taiyang structure and perforation hole size inversion from ultrasonic imaging logging data. The analysis result shows that low formation stress is conducive to opening efficiency of perforation cluster. If the density of the temporary plugging balls is large, it is easy to appear unstable plug and sometime fall off the perforation holes. And it is more inclined to plug the holes at the lower perforating section. This aggravates the appearance of non-uniform fracturing and "super hole". The four-parameter method of treating pressure increase, overlaying positive pressure difference, fracture indication (or pressure drop from abrasion) and stop pump pressure increase is proposed. It can provide a more comprehensive and accurate basis for the analysis and evaluation of temporary plugging effect. It is suggested that "variable density temporary plugging balls + temporary plugging agent" or line-connected temporary plugging balls could further improve the temporary plugging effect. This paper have guiding significance for optimization of multi-cluster temporary plugging fracturing scheme in horizontal wells.

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Section: Geological Featurementioning

confidence: 99%

Evaluation on effect of temporary plugging and diverting in operation of shale gas well fracturing based on ultrasonic imaging logging and suggestion on optimization of technological measures

chen,

wang,

chen

et al. 2024

Eighth International Conference on Energy System, Electricity, and Power (ESEP 2023)

View full text Add to dashboard Cite

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A Novel Naturally Fractured Reservoirs Classification Plot Through the Liaison of Dynamic Data, Depositional Environments and Rock Texture

Alcántara

Santiago

Paredes

et al. 2021

SPE Europec Featured at 82nd EAGE Conference and Exhibition

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Naturally Fractured Reservoirs (NFR) represent a challenge for petroleum industry because they are characterized by complex dynamics associated to the fluids motion and geological events that originated them million years ago, where diagenetic processes have played a transcendental role. In carbonates, the movement of fluids within the reservoir is highly influenced by the fracture systems present in the formation, however, these are intimately related to rock texture and quality, depositional environments, facies changes, regional and local stresses, tectonism and of course, diagenesis. Regarding the dynamic behavior, we can highlight the importance of the type of fluid present in the system and the acting drive indices, which govern the behavior of pressure and production in this type of reservoirs, whose analysis usually goes further of conventional techniques commonly used for its evaluation. One of the problems faced by reservoir engineers is the classification or categorization of these types of reservoirs to know their true potential and try to estimate the recoverable reserves as accurately as possible, since the complex dynamic behavior of NFR hinders its exploitation when the most important parameters for its correct evaluation are not known. From the above, a novel and practical Naturally Fractured Reservoirs (NFR) classification plot is proposed based on the Nelson's classification (2001) and a full revision of other author's technical reviews. The plot is generated through the information obtained from a full reservoir characterization to acquire petrophysical evaluations and Pressure Transient Analysis (PTA) to find the product of the effective porosity and the average flow capacity of each of the fields tested in order to plot them against the recovery factor; this analysis considered more than 200 carbonate fields from more than 40 countries around the world. When plotting the data involved, it is clear to see that they are grouped in different zones for its reclassification as Naturally Fractured Reservoirs, where we added a subcategorization of type II reservoirs (type II A and type II B) and also the influence of vugs in type I reservoirs and the gas and condensates region; all attributed to the dynamic behavior associated to the type of fluid, the acting drive indices, the depositional environments and the rock texture. The results obtained were fully coupled to a probability distribution and have shown to be consistent with the observed behavior, being a useful tool for determining the actual type of NFR, the expected production rates, the range of possible recovery factors to be achieved and the characterization of reservoirs. Likewise, the proposed plot can be applied to the analysis of sectors in the same reservoir or formation to try to identify the variations regarding the type of NFR by zones, blocks or compartments according to the location of each well in the field, considering their respective recovery factors concerning its cumulative production and original reserves.

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Modelling and Simulation of Acid Gas Absorption from Natural Gas by Amine Solution Using Aspen HYSYS

Ikpeze

Owolabi

Olateju

et al. 2021

Day 2 Tue, August 03, 2021

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This work has been carried out to model and simulate a typical acid gas absorption process using Aspen HYSYS process simulator. The chemical components involved in the process development were water, methane, ethane, propane, higher alkanes, carbon dioxide, hydrogen sulphide, nitrogen and amines: monoethanolamine (MEA), diethanolamine (DEA), triethanolamine (TEA) and methyldiethanolamine (MDEA). The fluid package selected for the simulation before entering the simulation environment was Acid Gas – Chemical Solvents. In the simulation environment, the model was developed by picking an absorber from the Model Palette, placing it and assigning the input and the output streams involved before inputting the parameters required for model convergence. The carbon dioxide-rich feed gas was made to enter the absorber at the bottom inlet stream while the lean amine stream entered at the top inlet and showered down on the uprising gas thereby trapping the carbon dioxide molecules within the gas. The top product from the absorber was the treated gas while the amine solution and the trapped carbon dioxide left the absorber as the bottom product. Different simulations were run to investigate the performance of the amines under the same operating conditions. It was discovered that, of all the four amine solvents considered in this work for the removal of carbon dioxide by chemical absorption, MEA had the highest efficiency but would require more dehydration because it had the highest water content. DEA was also found to scrub the carbon dioxide down to acceptable levels. However, TEA and MDEA barely scrubbed any carbon dioxide under these conditions, as their carbon dioxide compositions were found to be unacceptable. The analyses of the results obtained from the simulations indicated that Aspen HYSYS can be used to study the process of acid gas absorption successfully.

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Naturally Fractured Reservoirs and their Link to Tight and Shale Petroleum Reservoirs

Cited by 11 publications

References 50 publications

Evaluation on effect of temporary plugging and diverting in operation of shale gas well fracturing based on ultrasonic imaging logging and suggestion on optimization of technological measures

Evaluation on effect of temporary plugging and diverting in operation of shale gas well fracturing based on ultrasonic imaging logging and suggestion on optimization of technological measures

A Novel Naturally Fractured Reservoirs Classification Plot Through the Liaison of Dynamic Data, Depositional Environments and Rock Texture

Modelling and Simulation of Acid Gas Absorption from Natural Gas by Amine Solution Using Aspen HYSYS

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