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Further discussion of CO_(2) huff-n-puff mechanisms in tight oil reservoirs based on NMR monitored fluids spatial distributions

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petroleum Science 2023年第1期20卷 350-361页

作者： Wei-Yu Tang James J.Sheng Ting-Xue Jiang Unconventional petroleum Research Institute China University of PetroleumBeijing102249China bob l.herd department of petroleum engineering Texas Tech UniversityLubbockTX79409USA Sinopec Research Institute of petroleum engineering Beijing100101China

Due to the poor physical properties of tight reservoirs,CO_(2) huff-n-puff(HNP)is considered a potential enhanced oil recovery(EOR)method after primary depletion.Optimization plays a critical role in the effective implementation of CO_(2) huff-n-puff.But the optimization requires a good understanding of the EOR mechanisms.In this work,the spatial distribution of oil saturation under different experimental conditions was analyzed by the NMR method to further discuss the HNP mechanisms.According to the variation of 1D frequency signal amplitude,we divided the core into the hardly movable area and movable area,the region with the obvious signal decline was defined as the movable area,and the hardly movable area was the region with limited signal decline.Based on that the recovery characteristics of different scenarios were evaluated.Firstly,the necessity of the soaking stage was studied,where three scenarios with different soaking times were carried out.Secondly,the injection pressure was adjusted to investigate the effect of the pressure gradient.The T_(2) spectra show that soaking has significantly improved the production of crude oil in small pores,and higher oil recovery in a single cycle is observed,but it is lower when the elapsed time(total operation time)is the same.31.03% of oil can be recovered after 3 cycles HNP,which increases to 33.8% and 37.06% for the 4 cycles and 6 cycles cases.As the pressure gradient increases,more oil is removed out of the matrix,and the oil in the deep part of the reservoir can be effectively recovered.During the CO_(2) huff-n-puff process,the oil distributions are similar to the solution gas drive,the residual oil is distributed at the close end of the core and the range that the oil can be efficiently recovered is limited.

关键词： Tight reservoirs low-field nuclear magnetic resonance (NMR) CO_(2)huff-n-puff Enhanced oil recovery

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Experimental study on the degree and damage-control mechanisms of fuzzy-ball-induced damage in single and multi-layer commingled tight reservoirs

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petroleum Science 2023年第6期20卷 3598-3609页

作者： Chinedu J.Okere James J.Sheng li-Kun Fan Xiao-Wei Huang li-Hui Zheng Pan-Feng Wei bob l.herd department of petroleum engineering Texas Tech UniversityTXUSA College of petroleum engineering China University of Petroleum(Beijing)Beijing102249China China Changqing Oilfield Company CNPCXi'an710018ShaanxiChina Beijing lihuilab Energy Technology Co. Ltd.Beijing102200China

Fuzzy-ball working fluids(FBWFs)have been successfully applied in different development phases of tight reservoirs.Field reports revealed that FBWFs satisfactorily met all the operational and reservoir damage control requirements during their application.However,the damage-control mechanisms and degree of formation damage caused by fuzzy-ball fluids have not been investigated in lab-scale studies so far.In this study,the degree of fuzzy-ball-induced damage in single-and double-layer reservoirs was evaluated through core flooding experiments that were based on permeability and flow rate indexes.Additionally,its damage mechanisms were observed via scanning electron microscope and energy-dispersive spectroscopy tests.The results show that:(1)For single-layer reservoirs,the FBWF induced weak damage on coals and medium-to-weak damage on sandstones,and the difference of the damage in permeability or flow rate index on coals and sandstones is below 1%.Moreover,the minimum permeability recovery rate was above 66%.(2)For double-layer commingled reservoirs,the flow rate index revealed weak damage and the overall damage in double-layer was lower than the single-layer reservoirs.(3)There is no significant alteration in the microscopic structure of fuzzy-ball saturated cores with no evidence of fines migration.The dissolution of lead and sulfur occurred in coal samples,while tellurium in sandstone,aluminum,and magnesium in carbonate.However,the precipitation of aluminum,magnesium,and sodium occurred in sandstone but no precipitates found in coal and carbonate.The temporal plugging and dispersion characteristics of the FBWFs enable the generation of reservoir protection layers that will minimize formation damage due to solid and fluid invasion.

关键词： Drilling Fracture Fuzzy-ball fluids Formation damage analysis Muti-layer tight reservoirs Permeability damage index Flow rate damage index

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Coupled tripartite investigation of breaker fluid invasion and impact on hydrocarbon recovery in sandstone reservoirs

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petroleum Research 2023年第3期8卷 338-349页

作者： Stella I.Eyitayo Kazeem A.lawal Marshall C.Watson Oladoyin Kolawole Ibrahim Abdullahi Asekhame U.Yadua Oluchukwu M.Okoh Saka Matemilola Tunde Alabi bob l.herd department of petroleum engineering Texas Tech University807 Boston AveLubbockTX79409USA FIRST Exploration and petroleum Development Company(FIRST E&P) Nigeria John A.Reif Jr.Department of Civil and Environmental EngineeringNew Jersey Institute of TechnologyNewarkNJ07102USA Nigerian petroleum Development Company(NPDC) Nigeria

Breaker fluids are designed to dissolve filter cakes by breaking their long-chain molecules,thereby removing solid deposits on the wellbore wall.Although breaker fluids are not intended to infiltrate the hydrocarbon reservoir,they can invade and cause formation damage by altering sandstone reservoirs'wettability and relative permeability.This can lead to a reduction in the overall reservoir performance.This study coupled tripartite methods to investigate the potential impact of breaker invasion and transport in hydrocarbon reservoirs and its multiscale effect on the performances of sandstone reservoirs.We utilized experimental,analytical,and numerical methods to assess and predict the susceptibility of reservoirs to breaker fluid invasion and transportation.Our experimental and empirical investigations considered varying breaker fluid formulations to evaluate the effects of breaker fluid concentration,formation temperature,and solution gas-oil ratio(GOR)on residual-oil saturation(ROS)and oil-water relative permeability.By adopting the ROS and relative permeability associated with the 50%v/v breaker fluid mixture,the performance of the hydrocarbon reservoir was numerically simulated under the limiting scenarios of no-invasion,moderate-invasion,and deep-invasion of breaker fluid.The results indicate a positive correlation between breaker fluid concentration and ROS,highlighting the risks that breaker fluid invasion and deep infiltration pose to hydrocarbon recovery.Further,results show that both live-oil condition(lOC)and dead-oil condition(DOC)reservoirs are susceptible to the detrimental impacts of breaker fluid infiltration,while their invasion can reduce hydrocarbon recovery in both lOC(-6%)and DOC(-28%).The multi-scale effects on reservoir performance are more pronounced at near-wellbore and DOC than at far-field and lOC.Findings from this work provide valuable insights into the complexity of breaker-fluid invasion in sandstone reservoirs and the mitigation of associated risks to reservoir performance.

关键词： Breaker fluid Fluid invasion Formation damage Fluid transport Near-wellbore alteration

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Comparative study of well soaking timing(pre vs.post flowback)for water blockage removal from matrix-fracture interface

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petroleum 2020年第3期6卷 286-292页

作者： Nur Wijaya James J.Sheng bob l.herd department of petroleum engineering Texas Tech UniversityTexasUSA

Water blockage after hydraulic fracturing is one of the major challenges in shale oil recovery which affects the optimal production from the reservoir.The water blockage represents a higher water saturation near the matrixfracture interface,which decreases the hydrocarbon relative permeability.The removal of water blockage in the field is typically carried out by soaking the well(i.e.,shut-in)after hydraulic fracturing operation is finished.This soaking period allows water redistribution,which decreases the water saturation near the matrix-fracture interface.However,previous field reports show that there is not a strong consensus on whether shut-in is beneficial in terms of production rate or ultimate oil recovery.Due to the large number of parameters involved in hydraulic fracturing and tight formations,it is challenging to select which parameter plays the dominant role in determining the shut-in performance.Furthermore,literature on field case studies does not frequently report the parameters which are of researchers’interest.In other words,the challenge of evaluating shut-in performance not only lies on the complexity of parameters and effects involved within the reservoir,but also the limited number of field case studies which report a comprehensive list of fracturing and reservoir parameters.This paper aims to investigate the effect of well soaking timing on shut-in performance.This idea to investigate the shut-in timing effect is motivated by the fact that in the field,shut-in can take place either immediately after hydraulic fracturing but before the first flowback(i.e.,pre-flowback)or sometime after the first flowback(i.e.,post-flowback).The timing of shut-in is believed to influence the production performance,because it dictates how much water is allowed to imbibe from the fractures to the matrix before the extended production.A numerical model is built and validated by a successful history match with numerous data from core-flood experiments.Our previous study shows that shut-in performance depends heav

关键词： Water blockage Formation damage Flowback Shut-in Desiccation

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Optimization of acid fracturing for a tight carbonate reservoir

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petroleum 2020年第1期6卷 70-79页

作者： Aymen Al-Ameri Talal Gamadi bob l.herd department of petroleum engineering Texas Tech University2500 BroadwayLubbockTX79409USA

In this study,acid fracturing treatments were simulated for a tight limestone reservoir within a shale formation using FRACPRO software.The purpose was to investigate the optimum acid fracturing design that leads to a higher fracture etched length and width,and higher fracture conductivity.Moreover,the impact of the rock-acid contact time and whether to consider a post-flush or fluids flowback,on the acid fracturing outcomes were also investigated.A simple geological model was constructed which consists of different lithological layers.Different acid fracturing design scenarios were considered starting from a single stage of acid injection to multi-stage treatment.In multi-stage acid treatment,alternate acid-slickwater injection was considered.Plain HCl acids with different concentrations and other acids that are already included in FRACPRO database were used.The results showed that the acid loss during post-flush is among the main problems of the acid fracturing in tight carbonate shale reservoir.For the single stage of acid injection,it is recommended to flow back the acid after well shut-in instead of considering a post-flush stage.The multi-stage alternate acid slickwater injection reduces or even eliminated the acid loss.However,it is recommended to inject a slickwater before well shut-in to reduce the rock-acid contact time,thus reducing the formation damage.The results also showed that the created fracture etched width decreases and the fracture etched length increases as the fracturing stages increase.In this study,because of the low carbonate layer permeability and compressive strength,a two-stage alternate 28%HCl and slickwater injection with a post-flush stage is recommended.

关键词： Acid fracturing Tight carbonate Acid loss low compressive strength Single stage acid fracturing Multi-stage acid fracturing

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Optimal field development and production design for unconventional reservoirs:A case study from Central Sub-Basin,Permian Basin,New Mexico

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petroleum Research 2021年第1期6卷 66-76页

作者： Alexander Davis Oladoyin Kolawole Marshall Watson Chioma Onwumelu bob l.herd department of petroleum engineering Texas Tech University807 Boston AvenueLubbockTXUSA Harold Hamm School of Geology and Geological engineering University of North DakotaGrand ForksNDUSA

The planning and developmental decisions succeeding the discovery of an unconventional oil and gas field is of utmost importance in attaining successful exploitation and production from these tight reservoirs.The development and production of hydrocarbon from these unconventional reservoirs require requires adequate planning and execution which could be challenging,due to the sequence of heterogeneous lithologies of these formations.In this study,we designed and presented a comprehensive field development and production program that is representative of the unconventional oil and gas development in the Central sub-basin of the Permian Basin.To design and achieve optimal field development and production for unconventional reservoirs in the Central sub-basin of the Permian Basin,New Mexico,we utilized field data from an oil and gas well that was drilled to a TVD/MD of 2290 m with a PBTD of 2270 m.Subsequently,we conducted the petrophysical evaluation of the logs and utilized a decline curve analysis for reservoir evaluation of all the members of the formation.We also designed and developed comprehensive drilling,completions,and facilities programs.lastly,we incorporated an economic analysis of our optimized field development and production design.Our results provide a valuable plan and critical decision-making insight for optimizing field development and production of unconventional reservoirs in the Permian Basin and across the world.

关键词： Unconventional reservoir Carbonate Permian basin Field development Hydrocarbon production

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Effects of rock pore sizes on the PVT properties of oil and gas-condensates in shale and tight reservoirs

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petroleum 2018年第2期4卷 148-157页

作者： Arash Kamari lei li James J.Sheng bob l.herd department of petroleum engineering Texas Tech UniversityP.O.Box 43111LubbockTX 79409United States Southwest petroleum University ChengduChina

Shales make up a large proportion of the rocks with extremely low permeability representing many challenges which can be complex in many cases.A careful study of rock and fluid properties(i.e.PVT of shales)of such resources is needed for long-term success,determining reservoirs quality,and increased recovery factor in unique unconventional plays.In this communication,a comprehensive thermodynamic modelling is undertaken in which capillary pressure is coupled with the phase equilibrium equations.To this end,the data associated with both shale oil and gascondensates of Eagle Ford shale reservoir located in South Texas,U.S.,is used.Different properties,including bubble and dew point pressures,capillary pressure,interfacial tension,liquid and gas densities,and liquid and gas viscosities,are predicted observing the effects of rock pore sizes by the thermodynamic modelling performed in this study.The results demonstrate that the thermodynamic model developed in this study is capable of simulating the PVT properties of oil and gascondensates in shale and tight reservoirs.For a binary mixture 25:75 C1/C6,the bubble point pressure at different reservoir temperature is increased by increasing the pore sizes from 10 to 50 nm.Furthermore,an increase in pore sizes from 10 to 50 nm can increase the dew point pressure for a studied binary mixture 75:25 C1/C6.

关键词： Shale Pore size Oil Gas-condensate Thermodynamic modelling

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Simulation study of huff-n-puff air injection for enhanced oil recovery in shale oil reservoirs

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petroleum 2018年第1期4卷 7-14页

作者： Hu Jia James J.Sheng State Key laboratory of Oil and Gas Reservoir Geology and Exploitation Southwest Petroleum UniversityChengduSichuan 610500China bob l.herd department of petroleum engineering Texas Tech UniversityLubbockTX 79409USA

This paper is the first attempt to evaluate huff-n-puff air injection in a shale oil reservoir using a simulation approach.Recovery mechanisms and physical processes of huff-n-puff air injection in a shale oil reservoir are investigated through investigating production performance,thermal behavior,reservoir pressure and fluid saturation features.Air flooding is used as the basic case for a comparative study.The simulation study suggests that thermal drive is the main recovery mechanism for huff-n-puff air injection in the shale oil reservoir,but not for simple air flooding.The synergic recovery mechanism of air flooding in conventional light oil reservoirs can be replicated in shale oil reservoirs by using air huff-npuff injection strategy.Reducing huff-n-puff time is better for performing the synergic recovery mechanism of air injection.O2 diffusion plays an important role in huff-n-puff air injection in shale oil reservoirs.Pressure transmissibility as well as reservoir pressure maintenance ability in huff-n-puff air injection is more pronounced than the simple air flooding after primary depletion stage.No obvious gas override is exhibited in both air flooding and air huff-n-puff injection scenarios in shale reservoirs.Huffn-puff air injection has great potential to develop shale oil reservoirs.The results from this work may stimulate further investigations.

关键词： Air injection huff-n-puff Shale reservoirs Unconventional Air flooding Enhanced oil recovery

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Chip Flood (vs) Core Flood——Assessment of Flowback and Oil Productivity in Oil-Wet Hydraulic Fractured Rocks

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Open Journal of Yangtze Oil and Gas 2019年第1期4卷 59-78页

作者： Srikanth Tangirala James J. Sheng Jiawei Tu bob l.herd department of petroleum engineering Texas Tech UniversityLubbockUSA

New developments in lab technologies help us to explore problems that were less understood in the past due to the limitations and technological constraints. One such problem of assessing the formation damage created by the invasion of fracture fluid into the matrix at lab scale is the visualization of fluid saturation distributions inside the matrix. According to the current understanding, the high capillarity contrast between the fracture and the matrix creates a non-uniform saturation distribution of invaded fluid phase during flowback, with the saturations mostly concentrated at the fracture face. With the advent of microfluidics, their application has become more feasible to visually analyze the effectiveness of surfactants to mitigate the invasion-created formation damage and understand the impact of depth of invasion on the characteristics of flowback and oil productivity. Through our previous work, we have successfully demonstrated the capability of this new visualization tool in studying the factors of the presence of surfactant in the fracture fluid and its depth of invasion, to understand the flowback efficiencies and later oil productivities in oil-wet fractured formations. Since the substrate for flooding was a proxy model of an actual rock, the chip flooding results need to be validated with conventional core flooding experiments. In contemporary times, when the new advancements in technology are driving the research progress in all industries, it is mandatory to take a well informed decision by imposing a comparative check on the results with accessible conventional means, wherever possible. The success of validation of chip flooding approach with the core flooding approach in this work instates a strong belief over the application of microfluidics to pursue more research in related fields of oil recovery.

关键词： Chip Flooding Core Flooding Flowback Fracture Surfactant

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Discussion of the feasibility of air injection for enhanced oil recovery in shale oil reservoirs

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petroleum 2017年第2期3卷 249-257页

作者： Hu Jia James J.Sheng State Key laboratory of Oil and Gas Reservoir Geology and Exploitation Southwest Petroleum UniversityChengduSichuan610500China bob l.herd department of petroleum engineering Texas Tech UniversityLubbockTX 79409USA

Air injection in light oil reservoirs has received considerable attention as an effective,improved oil recovery process,based primarily on the success of several projects within the Williston Basin in the United States.The main mechanism of air injection is the oxidation behavior between oxygen and crude oil in the reservoir.Air injection is a good option because of its wide availability and low cost.Whether air injection can be applied to shale is an interesting topic from both economic and technical perspectives.This paper initiates a comprehensive discussion on the feasibility and potential of air injection in shale oil reservoirs based on state-of-the-art literature review.Favorable and unfavorable effects of using air injection are discussed in an analogy analysis on geology,reservoir features,temperature,pressure,and petrophysical,mineral and crude oil properties of shale oil reservoirs.The available data comparison of the historically successful air injection projects with typical shale oil reservoirs in the U.S.is summarized in this paper.Some operation methods to improve air injection performance are recommended.This paper provides an avenue for us to make use of many of the favorable conditions of shale oil reservoirs for implementing air injection,or air huff‘n’puff injection,and the low cost of air has the potential to improve oil recovery in shale oil reservoirs.This analysis may stimulate further investigation.

关键词： shale reservoirs reservoir

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