How can you optimize hydraulic fracturing treatments in tight sandstone reservoirs?

After all studies like, Reservoir characterisation, mineralogy study, log study , pressure study only then we go for fracturing. Hydraulic fracturing is simple but not much effective as it will work only in little fractured reservoir. For tight reservoir fracturing with chemical like hydrophloric acid is effective in tight clastic reservoir.

Reservoir Analysis: Thoroughly study the reservoir's properties and stress conditions to identify the most productive zones. Precise Well Placement: Accurately position wells to target the best areas for fracturing treatments. Advanced Fracture Design: Use simulation tools to design optimized fracturing treatments, adjusting fluid types and injection rates. Effective Proppant Selection: Choose proppants that maintain fractures' conductivity and prevent embedment. Real-time Monitoring: Utilize downhole sensors to monitor fracture growth and adjust treatments as needed. Post-Treatment Evaluation: Assess well performance to refine future fracturing techniques and improve results.

First, don’t expect optimum production from the first well, the learning may take a while. -Example the Barnett field: 1981 1st production; foam fracs 1985 Massive gel fracs 1997 water fracs lower costs 1999 Refracs restore production. 2003 Horizontal drilling expands Second, should identify the Clay minerals and Clay sizes (Porosity and Permeability) Third, we should identify the rock brittle or ductile Brittle = High Young, Low Poisson Ductile = Low Young, High Poisson

There could be the inclusion of advanced logging techniques like sonic logs, image logs, and nuclear magnetic resonance (NMR) logs, and geomechanical models could also be employed to understand the stress field and predict fracture growth, preventing unwanted fractures or early closure.

Je pense qu'en dehors des études plus haut citées il serait bon d'avoir une cartographie structurale très poussée pour déterminer les marqueurs de déformation (failles, plans de cisaillement...) contenus dans la roche cible. Ces marqueurs de déformation peuvent fournir les informations sur les séquences ou alors les phases de déformation subies par la roche et de prévoir les structures encore existantes et leur comportement face au fluide hydraulique injecté. La phase de déformation 1 peut avoir engendré certains plans structuraux qui même reprise par une autre phase tardive persistent encore. Si les fluides sont injectés de fa?on oblique à ces plans ces derniers vont plut?t guider ces fluides vers des directions inattendues .

? It is a key to the success of fracturing ? Controlled by the rock mechanical properties – Young modulus – Poison Ratio Should be well understood to prepare the fracturing technique and frac fluids Requires running a cross dipole sonic tool Provide compressional and shear data Requires the density tool as well for Young modulus Evaluation of rock mechanical properties

Theoretically its OK but practically no one knows the amount of effect and direction of effect. Offcourse effect will be much more in the direction in which fractures are opening.

La conception de la fracture doit également dépendre de la texture, de la structure du type de roche et de sa minéralogie. Pour éviter les désagréments environnementaux.

Analizadas más de 40 fracturas hidráulicas en areniscas de pozos Profundos HP-HT con permeabilidades menores a 10 miliDarcy en Monagas Venezuela. Se concluyó que el ancho de las fracturas era el parámetro geométrico más influyente en la productividad del pozo en el tiempo. Más que su longitud o altura. (simulada con frac pro/frac c.)

Production data must be examined over a period of many months, preferably years. It is the only way to track what fractures are really acheiving. Avoid excessive mathematical modelling.

I’ve never worked on fracture evaluation in tight sands. I have done surveillance logging on hundreds of heavy oil vertical wells drilled through maturing steam floods. For intervals containing steam (I.e. condensable vapor), we find that the most effective way to identify flow units and find remaining oil is to cool the well. On cooling, droplets of condensate form around the well and these droplets adsorb naturally occurring radon. This causes GR to temporarily increase by a factor of 10 or more. After warmback GR decreases to the original value because the droplets vaporize. If pressure and temperature are in the range where your reservoir is 2-phase, this patented process may dramatically change your view of the reservoir.

@Carlos: I do believe that in 10 mD or less, conductivity has a big impact in long term production but definitely such formation is not tight gas.

Generally clastic reservoirs are tight due to the presence of clay minerals like montmorelonite and illite. One is very sensitive to freshwater hence swells with fresh water so care must be taken while using HF with saline water.