Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Bahrami, Nick

doi:10.1007/978-3-319-02481-3

Cited by 6 publications

(5 citation statements)

References 20 publications

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“…Proper choice of working fluid can guaranty the success of well drilling and completion, different density fluids mean different wellbore pressure, which can be used to determine the invasion volume, depth and velocity to evaluate formation damage [12]. In normal well completion process, the fluid loss rate increases with the increasing of positive pressure differential, the high quality filter cake cannot be formed if the positive pressure differential is too low or may be breakdown by a higher positive pressure differential to make a greater invasion of the solid and water.…”

Section: Effect Of Well Fluid Density On Productivity Evaluationmentioning

confidence: 99%

The Effect of Well Completion Fluid Loss on Productivity Evaluation in Tight Sand Gas Reservoir: A Case Study from East China Sea Gas Well

Gao

Branch

Shang

et al. 2020

Int. J. Petrol. Technol.

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Fluid loss is inevitable in the well drilling and completion, which may cause series of formation damage such as clay swelling, solid plugging and water blocking. In tight sand gas reservoir, water blocking has become the major damage factor for economical developing. In deliverability test, water blocking will bring an inaccurate productivity test result to affect the following development strategy. With the development of East China Sea gas field, well drilling is focusing on the deeper tight sand formation. The tiny pore throat and high capillary pressure can bring out serious water blocking damage during well drilling and completion. The damaged zone can mislead the resource assessment and productivity evaluation. In this paper, an exploration well X in East China Sea gas field is selected as the research target to investigate the water blocking mechanism and physical process during well drilling and completion process. This study compares the productivity performance of X well with fluid loss and no fluid loss models through numerical modeling approach based on the actual data. Sensitive studies are also performed in the simulation. Results show that the excessive fluid invasion pressure and lower matrix permeability will result in serious water blocking damage to mislead the resource assessment and productivity evaluation even in underbalanced well drilling. Interestingly, extending shut-in time can make the gas production rate quickly reach the peak value in the early production stage, while it can decrease the cumulative gas production in whole production process. This study can provide an avenue to initiate quantitative analysis on resource assessment, and gas productivity evaluation strategy after water invasion during the well drilling and completion in tight sand gas reservoir of East China Sea.

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Section: Effect Of Well Fluid Density On Productivity Evaluationmentioning

confidence: 99%

The Effect of Well Completion Fluid Loss on Productivity Evaluation in Tight Sand Gas Reservoir: A Case Study from East China Sea Gas Well

Gao

Branch

Shang

et al. 2020

Int. J. Petrol. Technol.

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“…In order to estimate the skin factor related to phase trapping damage (S ptd ), the following equation using the end points on relative permeability curves can be used assuming that the effect of mechanical damage and other damage mechanisms are negligible (Bahrami et al, 2011): In cased-hole perforated wells, the large wellbore breakouts filled by cement behind casing reduce accessibility to reservoir rock, and affect well productivity negatively.…”

Section: Analytical Evaluations Related To Formation Damagementioning

confidence: 99%

“…In order to produce economically from such reservoirs, a long horizontal/deviated wellbore is required that can intersect the isolated sand lenses and connect them effectively to the wellbore through the high permeability conduits (Law and Curtis, 2002). The reduced jet penetration due to the rock tightness and the large wellbore breakouts filled by cement behind the casing, may cause penetration of the perforation jet into the tight formation not to be deep enough, and therefore the wellbore may not effectively be connected to the undamaged reservoir rock, causing low well productivity (Bahrami et al, 2011). In term of perforation efficiency in cased-hole completion system, tight reservoirs have high rock strength and penetration of the perforation jet into the tight formation may significantly be reduced compared with equivalent sandstone of higher porosity (Behrmann, 2000).…”

Section: Introductionmentioning

confidence: 99%

“…• Dusseault MB., (1993), Stress changes in thermal operations, SPE 25809, SPE International Thermal OperationsSymposium, Bakersfield, California • Empedrado Y.,Bahrami H., (2013). Near-Wellbore Formation Damage Effects on Well Performance: A Comparison Between Underbalanced and Overbalanced Drilling, SPE Production & Operations Journal, Volume 21, Number 1.…”

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Evaluation of Damage Mechanisms in Tight Gas Reservoirs: Field Example from Perth Basin

et al. 2015

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Tight gas reservoirs represent a significant portion of natural gas reservoirs worldwide. Production at economical rates from tight gas reservoirs in general is very challenging not only due to the very low intrinsic permeability but also as a consequence of several different forms of formation damage that can occur during drilling, completion, stimulation, and production operations. Tight gas reservoirs generally do not flow gas to surface at commercial rates, unless the well is completed using advanced technologies and efficiently stimulated. One of the major damage mechanisms in tight gas reservoirs is liquid phase trapping damage that is controlled by pore system geometry, capillary pressure, relative permeability and interfacial tension between the invading trapped fluid and reservoir fluid. The liquid invasion damage into the rock matrix reduces the near wellbore permeability as a result of temporary or permanent trapping of liquid inside the porous media, and results in low productivity in tight gas reservoirs. This study presents evaluation of damage mechanisms in tight gas reservoirs and the methods that can provide improved well productivity by minimizing damage to the formation. Numerical reservoir simulation is integrated with tight gas field data analysis and core flooding experiments to better understand the effect of different damage mechanisms on well productivity in order to propose the possible remedial strategies that can help achieve viable gas production rates from tight gas reservoirs.

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“…Water and oil redistribute in the fracture-matrix system during this countercurrent imbibition process. (Pagels et al, 2012;Bahrami, 2012;Holditch, 1979). Besides matrix imbibition, water can be retained in the secondary fractures (Pagels et al, 2012;Fan et al, 2010).…”

Section: Introductionmentioning

confidence: 98%

Numerical investigation of fluid-loss mechanisms during hydraulic fracturing flow-back operations in tight reservoirs

Wang

Leung

2015

Journal of Petroleum Science and Engineering

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Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Cited by 6 publications

References 20 publications

The Effect of Well Completion Fluid Loss on Productivity Evaluation in Tight Sand Gas Reservoir: A Case Study from East China Sea Gas Well

The Effect of Well Completion Fluid Loss on Productivity Evaluation in Tight Sand Gas Reservoir: A Case Study from East China Sea Gas Well

Evaluation of Damage Mechanisms in Tight Gas Reservoirs: Field Example from Perth Basin

Numerical investigation of fluid-loss mechanisms during hydraulic fracturing flow-back operations in tight reservoirs

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