2025-10-10 – Weekly Fracking News : Dissolvable plugs: cost-effective?

Last week, our community delved into the practicality of educational backgrounds in fracking, specifically whether a Petroleum Tech degree adds value. Discussions also focused on the utilizations of dissolvable plugs in high-TDS wells, exploring their cost-effectiveness and efficiency. Members shared insights into the geographical dynamics of fracking, debating which U.S. basin sees the most activity. Safety procedures and the depth of fracking wells were also on the radar, alongside lighter conversations about memorable on-site experiences.


This Week’s Hot Topics

Does a Petroleum Tech Degree Help in Fracking?
This thread explores the benefits and career impact of having a Petroleum Tech degree in the fracking industry. It’s a practical look at how education influences job opportunities and skills.
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Dissolvable plugs worth it in high-TDS wells
Members are debating the efficacy of dissolvable plugs in high-TDS environments. The conversation highlights real-world applications and cost considerations.
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What’s the Most Fracked U.S. Basin?
A lively discussion on the most active fracking basins in the U.S. This thread provides both historical and current perspectives on regional fracking activities.
Read more here

Do You Know How Deep the Average Fracking Well Goes?
This topic dives into the technical details of well depths, offering insights into average figures and the technology involved.
Read more here

Printable Safety Checklists and Rig Protocols
A practical resource thread providing downloadable safety checklists to enhance on-site safety and efficiency.
Read more here

Funniest Thing You’ve Seen on a Frack Site?
A lighthearted thread sharing amusing on-site incidents, bringing some humor to the demanding fracking environment.
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What’s the Weirdest Thing You’ve Eaten on the Job?
Another entertaining conversation where members recount unusual culinary experiences while on the job.
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Can You Name the Top Three Fluids Used in Fracking?
A technical discussion on fracking fluids, focusing on the most commonly used types and their purposes.
Read more here

FAQ/Guidelines
A helpful thread laying out the community guidelines and frequently asked questions for newcomers and veterans alike.
Read more here

Admin Guide: Getting Started
A guide to assist new members in navigating the forum and making the most of its features.
Read more here


Looking forward to another week of engaging discussions and shared knowledge. See you on the forum!

We’ve had dissolvables pay off in high-TDS (>150k ppm) Permian wells by front-loading a 0.25–0.5% HCl spear and a 12–24 hr warm soak to kick off Mg-alloy plugs — cuts out the mill and a day of coil. Caveat: if Ca/Ba/Sr are high, dose scale inhibitor or you’ll cement the seats instead of dissolving them. @J.Lopez, are you seeing slower dissolve when running straight produced water versus a blended brine?

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@marvin_v1970 Nice spear/soak play. In >150k ppm, we’ve improved Mg‑plug dissolution by preflushing 10–20 bbl of 3% acetic + 1–2 gpt GLDA to curb Ba/Sr scale, and we won’t soak unless BHT is >130°F — “Mg plugs hate cold water.” Do you run a 20–40 bbl clean‑brine sweep before flowback to catch partials, or skip it to save time?

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Quick datapoint: we won’t green‑light dissolvables unless a 190°F jar test with actual brine + about 0.3% HCl shows >20% mass loss in 60 min — otherwise they linger and idle the spread, … @marvin_v1970 your organic acid preflush is solid; we also tail 1–2 gpt phosphonate for 10–15 bbl after the spear to keep Ba/Sr scale from re‑precip and protect the “cost‑effective” part. What’s everyone’s dollar cutoff where you flip back to composite + CT — when a coil run is under ~$120k or when dissolution drifts past 24 hr?

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Cost-wise, I approve them only when BHCT >175°F and dual debris subs are in — thoughts, @marvin_v1970?

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For ‘cost-effective’, we green-light only when mill-out estimates exceed $100k; anyone tracking flowback solids vs remnants?

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gh‑TDS? Include the inhibitor package in the jar test; it can slow dissolution — agree, @marvin_v1970?

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In high‑TDS stages, I’ve cut costs by pumping a 10–15 bbl fresh‑water preflush right before setting each dissolvable; it drops salinity at the seat so the plug disappears within about 36–48 hrs instead of lingering. Small caveat: if bottomhole temp is under about 170°F, the benefit shrinks and I budget a short soak before flowback. @ops_ben, have you compared preflush vs no‑preflush on your last run?

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