Achieving uniform reservoir coverage during hydraulic fracturing remains one of the most critical drivers of estimated ultimate recovery (EUR). Operators frequently encounter a persistent operational bottleneck: uneven fluid distribution. Because stimulation fluids naturally follow the path of least resistance, they preferentially flood high-permeability zones or previously stimulated fractures, leaving tight, low-permeability rock un-stimulated.
To overcome this issue, progressive completion teams rely on Polyglycolic Acid (PGA). As an advanced, fully degradable aliphatic polyester, PGA acts as a high-performance temporary plugging agent. As explored in our comprehensive pillar guide, Polyglycolic Acid (PGA) Applications in Oil and Gas: Temporary Plugging Agents and More, PGA is a versatile biodegradable polymer used not only for fluid diversion, but also across degradable frac balls, structural rods, and downhole completion tools. In fracturing specifically, it temporarily seals off dominant fluid pathways, forcing fracturing fluid to redirect into untouched formation zones—all while preserving natural formation permeability.
Core Mechanism: How PGA Works in Frac Diverting
PGA diverting agents operate through a seamless two-phase process: high-strength mechanical bridging under differential pressure, followed by predictable chemical dissolution.
Powders
Micro-sealing matrix
High-Strength Granules
Perforation blocking
Microfibers
Fracture bridging network
Solid Spheres
Precision ball sealers
1 Mechanical Sealing & Bridging Action
PGA temporary plugging agents are engineered in diverse physical geometries—including powders, high-strength granules, microfibers, and solid spheres—tailored to specific perforation sizes and fracture geometries.
When slurry is pumped downhole, differential pressure drives the PGA particles directly toward high-intake zones. As particles aggregate across perforation tunnels or primary fracture mouths, they create a dense, low-permeability bridge.
2 Fluid Redirection (Diverting) & SRV Expansion
Once the PGA plug isolates the high-intake channel, wellbore fluid pressure rises significantly. This net pressure response alters local stress profiles, forcing subsequent fluid stages to crack open secondary, tight-gas or shale zones.
By systematically driving fluid into untouched rock matrix, PGA significantly expands total Stimulated Reservoir Volume (SRV) and boosts single-well productivity.
Maximize Your Well Productivity with Our High-Performance PGA Solutions
Achieving precise fluid redirection requires reliable, high-purity materials engineered specifically for harsh downhole conditions.
Our company provides a full suite of custom-engineered PGA temporary plugging agents, including precision-sized PGA granules, high-tensile fibers, and hydrolytic degradation-controllable PGA plugs designed for temperatures ranging from 40°C to 150°C.
- Custom Mesh & Particle Size Distribution (PSD): Tailored to your specific perforation geometry.
- Predictable Degradation Timelines: Matching your exact stimulation schedule.
- Global Logistics & Technical Field Support: Ensuring seamless completion operations.
Technical Comparison: PGA vs. Conventional Diverting Agents
Selecting the right diverting agent directly impacts completion operational cost and post-frac well cleanout. The matrix below highlights why PGA outperforms traditional materials like PLA and Benzoic Acid:
The Operational & Economic Advantages of PGA
Beyond fluid diversion, PGA delivers clear financial ROI across the entire completion lifecycle:
Zero-Residue Hydrolysis
PGA hydrolyzes completely into water-soluble glycolic acid, which eventually breaks down into harmless H2O and CO2. This leaves no polymeric skin or insoluble residue behind to clog pore throats or proppant packs.
Elimination of Mechanical Intervention
Because PGA degrades fully on a predictable schedule, operators eliminate costly coil tubing drill-out runs. This significantly reduces rig time, lowers operational risks, and delivers measurable cost savings per well treatment.
Versatility in Severe Downhole Environments
Advanced PGA formulations can be engineered for low-temperature tight gas wells as well as high-temperature/high-pressure (HTHP) deep reservoirs, ensuring reliable degradation rates across varying bottomhole temperatures (BHT).
By integrating PGA temporary plugging agents into your completion workflow, operators achieve optimal diversion efficiency, safeguard reservoir conductivity, and maximize overall return on investment.