Understanding the Composition and Challenges of Fracturing Flowback Fluid
Composition of Fracturing Flowback Fluid
After the completion of fracturing operations, the mixture of liquids returning to the surface from the wellbore is collectively referred to as fracturing flowback fluid. Its composition mainly includes the following parts:
1. Post-operation flowback fracturing fluid and broken gel fluid: This is the primary component of such waste fluids. During the fracturing process, high-pressure working fluids (i.e., fracturing fluids) are injected into the well to enhance reservoir permeability. After entering the rock formation, the polymers contained in this fluid (such as guar gum, etc.) degrade under the effect of formation temperature, turning into broken gel fluid. Upon completing the production enhancement task, this broken gel fluid mixes with crude oil, water, and other substances within the formation and is expelled to the surface together.
2. Remaining base fluid that did not enter the formation: Before pumping, fracturing fluids need to be formulated, during which various chemical additives (such as preservatives, breakers, etc.) are added to adjust their properties. After the completion of construction, those original gels (i.e., base fluids) that did not enter the rock formations also return to the surface along with the broken gel fluid.
3. Wastewater generated from washing operations: Before and after fracturing operations, active water is usually used to clean the wellbore to remove impurities and residues. This operation generates a large amount of wastewater, which ultimately merges into the flowback fluid system.
4. Other mixed liquids: In addition, flowback fluids may also contain formation native water, rainwater, and other liquids mixed during the operation process, forming the final surface discharge.
Characteristics of Fracturing Flowback Fluid:
1. Complex composition: Containing various pollutants including oil, suspended solids (SS), guar gum, various agents, etc., these pollutants are diverse in type and high in content.
2. High viscosity, severe emulsification: The viscosity of fracturing flowback fluids is relatively high, with a severe degree of emulsification making separation difficult. Some fracturing flowback fluids can have viscosities reaching 10~20mPa·s, and severe emulsification makes the discharged fracturing wastewater viscous and odorous.
3. Water quality and quantity fluctuate greatly: Water quality and quantity of fracturing flowback fluids often exhibit significant fluctuations, imposing high demands on the shock resistance and stability of treatment equipment.
4. Difficult to treat: Due to the numerous types and high content of organic substances in fracturing flowback fluids, coupled with high COD (Chemical Oxygen Demand), TDS (Total Dissolved Solids), and TSS (Total Suspended Solids), it poses significant challenges for treatment, leading to higher treatment costs.
Sinokle's Process
Using CDOF and CDFU patented technologies as core processing equipment, combined with efficient filtration and fine filtration technology, Sinokle achieves efficient and rapid treatment of fracturing flowback fluids, ensuring that the effluent meets the customer's on-site processing requirements.
Based on years of practice in oil and gas field development and production, Shenzhen Sinokle has developed comprehensive solutions for the treatment and comprehensive utilization of fracturing flowback fluids based on a full lifecycle analysis of water resources during the oil and gas field development process. They have independently researched and developed several patented technologies for the reuse and reinjection treatment of fracturing flowback fluids, capable of meeting different customer needs and varying water quality treatment requirements.
