Resources / Field Q&A
Problems We've Seen —
And How We Fixed Them
Real challenges from real upstream operations, with practical, field-tested answers. If you're seeing it, we've likely solved it.
How to use this page: Each section covers a common challenge we've encountered working with upstream operators. Click any question to expand the full answer. If your situation needs a closer look, use the contact button below each section.
LOE & Cost Issues
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This is more common than you'd think, and the good news is there are clear ways to audit it.
Platforms like Engage and Field Flow exist specifically to QC water hauler data and ensure you're billed only for actual water hauled — these are worth evaluating if you're moving significant volume.
If you're working through a SQL database, it's possible to pull water production and barrels hauled per well into a BI dashboard and investigate discrepancies directly — comparing what was reported versus what the hauler invoiced.
Start by pulling 90 days of tickets and cross-referencing against your production-reported water volumes well by well.
Bottom line: Don't accept invoices at face value. A single audit often uncovers thousands of dollars in discrepancies — and putting a system in place prevents it going forward.
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High compression costs are often a sign of over-sizing, over-injection, or missed renegotiation opportunities. Here's how to approach it:
Evaluate your current injection rates — many fields are over-injecting, which drives up costs without a production benefit.
Consider downsizing compression where wells have depleted and current units are oversized for actual volumes.
Compare rates across vendors and negotiate — this is often left on the table for years. Don't forget to account for fuel burn in your total cost comparison.
Monthly meetings with each rental company, attended with downtime data and audit results in hand, create accountability and often lead to rate reductions.
Quick win: Pull your last 12 months of compression invoices by unit and map them to current production volumes. Oversized units on depleted wells are usually the fastest savings.
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High spend with poor performance usually means the program hasn't been critically reviewed in a long time. Start here:
Has a third-party performance test been conducted on your common chemicals? Vendor-run tests have obvious conflicts of interest.
When was the last time you formally bid out the chemical program? Even every 2–3 years is worth a competitive bid to reset pricing.
Are your field employees actively checking chemical rates and confirming deliveries? Inconsistent injection is often the real culprit behind persistent corrosion.
Evaluate whether bringing the program in-house makes financial sense — many operators find this cuts cost by 30–50% while improving accountability.
Pro tip: Separating the performance audit from your current vendor relationship is critical. A third-party chemical audit often pays for itself in the first month of adjustments.
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Expensive slick line jobs are almost always a maintenance problem, not a slick line problem.
Is there a preventative maintenance program in place to routinely R&R downhole equipment? Spending $500–$1,000 bi-annually for a spring check catches failures before they become catastrophic.
Fishing an intact spring fits within minimum hourly and tool charges. Fishing a broken spring becomes a full-day or multi-day job with multiple additional tool charges and significant well downtime.
Leaving broken equipment downhole to avoid cost creates a different problem — restrictions in the wellbore and increased risk of broken pieces entering the plunger system, triggering yet another callout.
Review your vendor's pricing structure against competitors annually — rates vary significantly and are often negotiable with volume commitments.
Rule of thumb: A proactive spring check program at $500–$1,000/year almost always costs less than one reactive fishing job. Prevention is the cheapest slick line call you'll ever make.
Production Performance
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Missing decline targets typically comes down to one of a few repeatable causes:
Over-injection:Injecting too aggressively creates a downhole restriction that limits reservoir contribution. Check injection volumes well by well against current reservoir pressure.
Frequent compressor downtime:Every hour a compressor is down, you're losing production and often causing liquid loading or backpressure issues that compound the decline.
Plunger programs not being maintained:Plungers not being physically checked or changed, settings not updated as wells deplete — these are quiet, consistent production killers.
Run a well-by-well comparison of actual vs. target decline, then categorize each deviation by probable cause. This prioritization step is often skipped, and it's where the most time gets wasted.
Start here: Pull your plunger arrival data for the last 30 days and compare cycle efficiency to 90 days ago. Degrading performance shows up here first.
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Sand migration is a mechanical problem that requires a mechanical solution — and patience. Here's the playbook:
Flow control:Sand often sweeps through the lateral into the tubing due to brief, excessive flow rates — typically caused by long shut-ins or unloading large fluid slugs. An automated throttling valve controls the rate and allows sand to flow out at a manageable pace rather than all at once.
Slower, more methodical pump jobs:Aggressive pump rates accelerate sand movement. Slowing down and taking a more deliberate approach reduces the volume of sand mobilized per event.
Preventative maintenance:Regular inspection of tubing and downhole equipment to catch sand accumulation before it creates a full restriction or equipment failure.
Key insight: The instinct to flow harder to "blow out" the sand usually makes it worse. Controlled, slower flow rates almost always produce better long-term outcomes on sand-prone wells.
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Flat production looks good at a glance, but it's worth investigating the cause — not all flatness is natural.
The well may be mechanically choked back — either by a physical choke or a "clock choke" where your plunger timing settings are limiting flow time and effectively capping production artificially.
Over-injection may be creating a downhole restriction that's preventing the full reservoir contribution from reaching surface. The well looks stable because it's consistently underperforming at the same level.
Review plunger cycle data and injection volumes before assuming flat is healthy. A quick SCADA audit will usually surface the pattern.
Test it: If you haven't updated plunger settings in the last 60–90 days and the well has been flat, try loosening the clock settings incrementally and monitor the response over 2–3 cycles.
Equipment & Downtime
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Chronic compressor downtime is almost always a relationship and accountability problem as much as a mechanical one. Here's the system that works:
Downtime tracking:You can't manage what you're not measuring. Build a simple downtime log by unit, by cause, and by vendor. This becomes your leverage.
Routine site inspections:Regular physical checks catch early warning signs before they become full failures. Assign inspection cadence by criticality of each unit to your production targets.
Monthly vendor meetings:Show up with your downtime data and audit results in hand. Vendors respond to operators who are organized and tracking performance. Most improve their response times significantly once they know they're being held accountable.
Consider a Coordinator or Manager role:If you're managing a large enough fleet of rental units, a dedicated position to own vendor relationships and downtime tracking pays for itself quickly.
The shift that matters: Move from reactive (calling when it's down) to proactive (tracking trends, meeting monthly, anticipating failures). That mindset change alone typically cuts downtime by 30–40%.
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Frequent plunger equipment failures almost always trace back to one of a few root causes. Work through these questions:
How much fluid are you producing?High fluid loads stress plunger equipment significantly — the type and size of plunger needs to match actual production conditions, not what was installed at initial setup.
What size and type of plunger are you running?Running the wrong plunger for your wellbore conditions is one of the most common and overlooked causes of premature failure.
What is your surface flow path?Restrictions, sharp bends, or undersized surface equipment create impact points that break equipment on arrival.
How much variance in line pressure are you seeing during each plunger cycle?High variance — especially pressure spikes — indicates the plunger is arriving too hard or too fast, which causes most of the surface equipment damage.
Where to start: Pull arrival pressure data for your worst-performing wells and look for consistent pressure spikes on arrival. That single data point usually tells you whether it's a sizing issue, a settings issue, or a surface equipment issue.
People & Retention
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Pay matters, but experienced operators leave for reasons that often have nothing to do with their paycheck. Here's what actually drives retention:
PTO and work-life balance:Operators need enough time off for vacations, appointments, and sick days. Rigid schedules with no flexibility are a top reason good operators leave — especially when callouts are frequent.
Schedule flexibility:There are many ways to maintain coverage while offering flexibility. Allowing an operator to leave midday for a child's lunch and complete the route afterward costs you nothing and builds significant loyalty.
Callout structure:Operators despise being on-call constantly or getting called out repeatedly at night. Evaluate each pad — if a well goes down overnight, what's the actual net revenue impact? Is an emergency callout really justified? Safety also becomes a real concern when operators are running on no sleep.
Meaningful responsibilities:Operators who feel challenged and needed stay longer. Filling the workday with purposeful tasks (not busywork) keeps engagement high and makes the job feel worth doing.
Pay structure:A flat starting rate that ignores experience limits your hiring pool immediately. Build in experience-based starting points and a clear path to increases.
The real insight: Most experienced operators who leave could have been retained with one or two small structural changes. Exit interviews — even informal ones — almost always reveal preventable reasons for leaving.
Reporting & Visibility
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This is a reporting structure problem — not a people problem. The answer is building the right cadence and format before something goes wrong.
Morning report:A brief daily summary of what's down, why, and what's being done about it. Operators can do this in 5 minutes if the format is simple and consistent.
EOD report:Status update on anything flagged in the morning — what was resolved, what's still open, what's expected overnight.
Weekly higher-level reporting:Production totals, downtime summary, and LOE flags rolled up for management review.
Quarterly route reviews:A structured sit-down between foreman and each operator to walk through their wells, flag recurring issues, and align on priorities. This is where most chronic problems get caught before they become expensive ones.
The fix is simple: Build a one-page morning report template and make it a daily non-negotiable. Within two weeks, you'll spend less time chasing answers and more time making decisions.
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Accelerated facility degradation almost always means inspections aren't happening on a consistent schedule — or aren't being documented when they do.
Annual site inspection per location at minimum:A full walk-through of each site with a standardized checklist covering equipment condition, corrosion indicators, containment integrity, and safety items.
Document everything:A photo log and inspection record creates accountability and gives you a baseline to compare year over year.
High-value or high-risk sites may warrant more frequent inspections — quarterly is appropriate for critical facilities or locations with known integrity concerns.
Assign ownership — if no one is specifically responsible for inspection follow-up, action items disappear. One person, one list, clear deadlines.
Quick start: Build a simple 1-page site inspection form, assign one person per area to complete it annually, and track completion in a shared spreadsheet. Consistency matters more than complexity here.
Facing a Problem That Isn't Listed Here?
Every operation is different. Tell us what you're up against, and we'll give you a straight answer — no sales pitch required.