Published Date: June 23, 2026

“Let’s start at a situation where we are drilling a 10,000 ft horizontal well in a prospective but yet undrilled shale play,” Jessica Fallon starts her explana­tion, “and we frac the shale along the full horizontal length of the well. The frac is pumped in isolated stages along the wellbore and can easily take between one and two weeks to complete. Follow­ing the last frac stage, there is a period of flowback, then the well is put on pro­duction, and everybody is happy.”

Then, some years later, in order to maximise the recovery of hydrocar­bons from the lease, companies often drill a child well at a limited distance from the parent well. That’s when problems tend to arise.

“While frac’ing the child well,” Jessica says, “we sometimes observe a pressure spike in the parent well.” In other words, a connection is estab­lished between the parent and child well. This can cause the parent well to produce fluid and even sand from the child well’s frac. In some cases, a drop in production rate is observed in the parent well, too, with the ultimate recoverable volumes being negatively impacted.

A: Well sticks for parent and infill wells. B: How a frac hit can both have a positive as well as a negative impact on production from the parent well. In the production graphs, there is a period of a few weeks before and after the frac where the parent well was likely shut in to try and mitigate the impact of the offset frac, and then (after) flowing back water and recovering from the frac hit. There is a little gap in boe and water production for the shut-in time, and then after that, a longer period of “flowback” where the frac water is being produced, and then after that, an uplift in production (boe) as a result of the 2017 interaction. The 2019 frac hit is catastrophic because it knocks the well completely offline – it stops producing hydrocarbons and only flows water, unlike in 2017, it doesn’t recover. It is pretty far along on its production profile, so close to the end of its life anyhow, but it might have carried on with a low rate for a good while longer. Liu et al. (2023) – URTeC: 3873139.

“The way I see it,” says Jessica, “is that production from the parent well changes the stress pattern in the subsurface, creating a “pressure sink” around the parent well. This causes the fractures from the child well to preferentially make their way in the direction of the parent well. These fracs are “captured” by the lower pressure rock around the parent well instead of opening up new rock for the child well.”

To prevent situations like that, wells tend to be drilled at larger dis­tances from each other than in earlier years when this phenomenon was not recognised yet. Around ten years ago, when shale was still in its early days, a distance of around 600 ft was quite common; these days it is more in the order of 1,000 ft.

Another way to prevent the issue is to drill multiple adjacent wells from a single pad and frac them all at once, before any production or pressure depletion occurs. It is also possible to map pre-existing fracture systems in the shale using seismic attributes, and decide not to frac some inter­vals in the well where you think it is likely for faults to connect, but that always needs to be balanced against the loss of production. “You can im­agine that is a difficult discussion,” concludes Jessica.