propel ssp

Reduce your cost per boe. REQUEST A QUOTE

THE PROOF IS IN THE DATA.

We’re proving our proppant where it matters most—out in the field. Read these case studies to see how we have helped other companies reduce their cost per BOE out in the real world. We’re committed to do more field trials and bring you more data in the future.

THE RIGHT PROPPANT MATTERS.

We know that every well is unique, and there are many factors and conditions you need to consider when selecting the right proppant. The information below can help you determine which proppant to use under a variety of unique challenges.

Preventing Proppant Flowback

During proppant flowback, proppant flows out of reservoir fractures and back up into the wellbore, causing costly repairs and nonproductive time. Curable resin-coated sand prevents proppant flowback by setting into a pack, which keeps raw sand in the fractures to improve well performance. CoolSet® curable resin-coated sand sets without activator in reservoir temperature as low as 100° F. OptiProp® curable resin-coated sand, which also prevents proppant flowback, offers superior conductivity.

Technical Paper: The Long-Term Economic Value of Curable Resin-Coated Proppant Tail-in to Prevent Flowback and Reduce Workover Cost
Published Article: How curable resin-coated proppant tail-in prevents proppant flowback, reduces workover costs
Published Article: Curable resin-coated proppant prevents proppant flowback
Proppant Brief: Parameters That Affect Proppant Flowback

Reducing Water Consumption

Hydraulic fracturing fluid, which is 90%+ water, carries proppant into low-permeability formations. With multiple frac stages, a horizontal well requires more than six times the amount of water than a vertical well. A fluid sweep, which moves into the formation large amounts of sand that have fallen out of the fluid, requires more water. Propel SSP® proppant transport technology, which eliminates fluid sweeps, is a better approach. Propel SSP places proppant higher and deeper into the formation without settling.

Video: Propel SSP Technology Tail-In vs. Slickwater Simplified Design

Reducing Embedment

Uncoated frac sand and ceramic proppant are known to embed into clay-rich, soft formations reducing fracture width and, ultimately, fracture conductivity. Embedment can occur initially during pressure pumping and worsen with the formation’s continuous softening and swelling. Curable proppants, such as, CoolSet® curable resin-coated sand, OptiProp G2® curable resin-coated sand, and Super LC® curable resin-coated sand effectively set into a proppant pack. The proppant pack has an overall greater surface area that redistributes and lowers the proppant force against the formation. The proppant pack reduces single-point loading that, in turn, minimizes embedment to maintain fracture width and enhanced conductivity.

Proppant Brief: Curable Resin-Coated Sand Mitigates Proppant Embedment to Increase Well Net Present Value

Reducing Formation Damage

Slickwater, one of the most popular fracturing fluids because of lower cost, and linear gel and crosslinked gel, which increase the frac fluid’s proppant-carrying capacity, damage proppant pack conductivity and formation permeability. In guar-based systems, for example, 6% to 10% of insoluble residue is deposited on the shale, harming hydrocarbon production. With Propel SSP® proppant transport technology, the the fluid system and proppant pack are one in the same. The technology, which is compatible with most fluid chemistry, leaves no residue in the formation after the polymer is stripped from the proppant with a conventional breaker. The undamaged proppant pack and formation enable increased conductivity for better hydrocarbon production.

Webcast: Efficient Proppant Transport: Just Add Water
Video: Propel SSP Technology vs. Slickwater

Reducing Proppant Pack Damage

Slickwater, one of the most popular fracturing fluids because of lower cost, and linear gel and crosslinked gel, which increase the frac fluid’s proppant-carrying capacity, damage proppant pack conductivity and formation permeability. In guar-based systems, for example, 6% to 10% of insoluble residue is deposited on the shale, harming hydrocarbon production. With Propel SSP® proppant transport technology, the the fluid system and proppant pack are one in the same. The technology, which is compatible with most fluid chemistry, leaves no residue in the formation after the polymer is stripped from the proppant with a conventional breaker. The undamaged proppant pack and formation enable increased conductivity for better hydrocarbon production.

Video: Propel SSP Technology Tail-In vs. Hybrid System
Webcast: Efficient Proppant Transport: Just Add Water

Curing in Low-Temperature Wells to Prevent Proppant Flowback

In low-temperature formations, such as in the Permian Basin and Midcon, reservoir closure stress alone is inadequate to initiate the setting of a proppant pack to prevent proppant flowback. In this type of application, an activator promotes curing; a proppant that does not require activator is another solution. CoolSet® curable resin-coated proppant sets in fractures without activator and prevents proppant flowback at reservoir temperature of 100° F. This reliable proppant, which has high unconfined compressive strength (UCS), conductivity, and crush resistance, enhances oil and gas production.

Proppant Brief: Choose the Right Proppant

Eliminating Fluid Sweeps to Mitigate Settling and Pressure Spikes

The industry has documented for decades how frac sand in a slickwater or gel fluid settles and forms a dune before reaching the fracture tips. With duning, there is also the risk of a screenout that causes costly nonproductive time. Another approach to move the proppant dune is a fluid sweep, requiring additional water. Propel SSP® proppant transport technology eliminates fluid sweeps, decreases water consumption, and places proppant farther and higher in the fractures without duning.

Video: Propel SSP Technology Tail-In vs. Hybrid System
Published Article: Making frac proppants go farther
Webcast: Efficient Proppant Transport: Just Add Water

Eliminating Proppant Flowback During Refracing

Operators have a great opportunity to increase production with refracturing, which repairs reservoir damage. Wells that could be good candidates for refracturing had the wrong proppant originally, resulting in reservoir damage by formation fines, crushed proppant, or embedded proppant. During refracing, a diverting fluid agent (DFA), such as a biodegradable ball sealer, seals off the original perforations before new clusters are fractured. This process is repeated for each refraced stage, in addition to pumping quality curable resin-coated sand. Curable sand, which sets into a pack, prevents proppant flowback and significantly reduces fines and eliminates embedment.

Proppant Brief: Improve Well Economics with Refracturing

Fracing HP/HT Wells and Reducing Fines

In higher-pressure wells, such as the 12,000+ psi wells in North Dakota’s Bakken formation, choosing the right proppant is critical. A quality resin-coated sand must meet The International Organization for Standardization (ISO) 13503-2 standards. An inferior resin-coated sand will set prematurely at the wellbore or be crushed into fines. These proppant fines cause severe well production loss by clogging the fracture and reducing hydrocarbon flow from lower conductivity. In the Bakken, PowerProp® precured resin-coated sand offers superior conductivity, crush resistance, and proppant flowback control.

Proppant Brief: Resin-Coated Proppant Withstands the Highest Reservoir Temperature and Pressure

Fracing in Low Bottomhole Temperature and Low-Pressure Wells

Some reservoirs in Canada or New Mexico have a temperature range of 70° F to 90° F. These low bottomhole temperatures require a proppant that can set at 70° F without activator to prevent proppant flowback and minimize embedment. This proppant must also have high conductivity and crush resistance for increased hydrocarbon production.

Proppant Brief: Fines Reduce Long-Term Oil and Gas Production

Increasing Conductivity in Low-Pressure Wells

In low-pressure wells, resin-coated sand offers compelling value. A quality resin-coated sand increases conductivity by effectively holding the fracture open to allow hydrocarbon flow. Our curable and precured resin-coated sand increase a well’s net present value, increasing conductivity in low-pressure wells.

Proppant Brief: Precured Resin-Coated Proppant Increases Net Present Value

Increasing Crush Resistance and Reducing Fines

Fines, which comprise crushed fracture proppants and formation fragments, are generated during hydraulic fracturing and after when the formation applies strong pressure. Fines can plug the fracture especially in the near-wellbore area, which lowers conductivity and hydrocarbon production. A desire to reduce cost in the initial completion by pumping raw sand may result in continuous fines generation. Our curable and precured resin-coated sand products encapsulate fines for superior conductivity.

Proppant Brief: Will a High Flow Rate Break the Bond of Curable Resin-Coated Proppant?

Increasing Production Through Conductivity

Resin-coated sand—compared with Northern White or other frac sand—has superior crush resistance. The resin encapsulates fines that can be generated if the proppant is crushed by reservoir closure stress. Curable resin also forms a strong pack to prevent proppant flowback. Raw sand loses 30% to 35% of its conductivity between 150° F and 250° F while the conductivity for resin-coated proppants remains unchanged at this temperature range. When raw sand does not offer the required strength to optimize conductivity, crush resistance, and proppant flowback control, choosing THS® precured resin-coated sand, for example, will increase a well’s production and net present value.

Case Study: PowerProp Precured Resin-Coated Proppant Increases Revenue by $770,000 per Well in Three Wells
Proppant Brief: Proppant Shape Enhances Performance

Sealing Fractures Temporarily During Refracing

During refracing, a diverting fluid agent (DFA), such as a biodegradable ball sealer, is necessary to seal off the original perforations. The sealer diverts frac fluid flow so new clusters can be fraced. This process is repeated for each refraced stage. BioBall biodegradable ball sealers are field-proven DFAs.

Product Information: BioBalls

CONTACT US

Have a Fairmount Santrol Sales Representative contact you.