Hiltek Resource Recoverywith BioActive Services

Well economics

Lifting Costs and Well Life

A stripper well lives on a thin margin: what a few barrels a day sell for, minus what it costs to lift them. Paraffin, H₂S, iron sulfide, asphaltenes, scale, emulsions and corrosion widen the cost side every month, in treatments, lost oil and downtime, and they bring forward the day a well stops paying and is plugged with oil still in the ground.

Where the money goes

Treatment costs are ongoing and rising, and many treatments harm wellbore health

None of these problems stays fixed. Each treatment removes only what has already formed while the oil and the well’s biology build it again, so the bills come back every month and grow as the well ages. And several of the usual fixes do harm of their own: hot oil can push wax into the formation, acid frees more H₂S, and biocides miss most of the bacteria sheltered in slime.

ProblemUsual fixThe catch
ParaffinHot oil or water, solvents, scrapingBack every 30 to 90 days; melted wax can damage the formation
H₂SScavengers, biocidesThe bill rises with every ppm; the bacteria keep making more
Iron sulfideAcid jobs, cleanoutsAcid frees toxic H₂S; deposits re-form
AsphaltenesXylene soaks, inhibitorsLight solvents can knock out more; inhibitors don’t last
ScaleInhibitor squeezes, acid, millingA squeeze lasts 3 to 12 months
EmulsionsDemulsifiers, heatTreats only the batch in the tank
CorrosionInhibitors, biocides, new steelCan’t reach the steel under the slime

Costs, details and sources are on each root-cause page.

Lost production

Restricted flow, deferred barrels

A partial blockage cuts the daily rate. A full restriction, a hung rod or a parted rod string stops the well until it is cleaned out or fished, and every one of those days is oil not sold.

73%
of the tubing’s flow area closed by ½ inch of wax
around a ¾-inch rod in 2⅜-inch tubing
~730 lb
added to every 1,000 ft of rod string
by the same ½ inch of wax
Days
of downtime for a fishing job
when the rods part under the load

Wax figures from the Hiltek and BioActive presentation. More in Paraffin and Iron sulfide.

The economic limit

Higher lifting costs shorten a well’s life

A well reaches its economic limit when the oil it sells no longer covers the cost of producing it. Every dollar of lifting cost raises the cost per barrel and the break-even price, and moves that day closer. Treating the cause moves it back.

One 1.5 BOPD stripper well at $60 oil: without → with MEOR

  • Lifting cost per barrel, treatment included$26.67 → $23.33
  • Break-even oil price$33.76 → $29.54
  • Net profit a month$933 → $1,300
  • Profitable life8 → 17 years

$1,200 a month in lifting costs, output falling 4% a year and costs rising 4% a year. With MEOR, lifting costs are cut 20% before the $300 monthly treatment is added, with 20% more oil and output falling 0.5% a year. From Hiltek’s stripper-well proforma: see the proforma example. Illustrative values, not a forecast for any specific well.

Also applies to injection wells

Stabilize the well, and turn the decline curve positive

Removing deposits, and the biology that keeps rebuilding them, lets a well hold its rate longer. In treated wells, oil output climbed and then held while treatment continued: see Case Studies.

The plugging bill

When the well stops paying, the bill comes due

When keeping a well flowing costs more than it will earn in its remaining life, it is shut in or plugged, often well before the reservoir is depleted. The oil left behind is usually lost for good, and the plugging bill arrives with no revenue left to pay it.

$20,000
median cost to plug a well
$76,000 with surface reclamation (Raimi et al., 2021)
$50–100K+
what decommissioning a well can now top
American Bar Association, 2026
141,959
documented orphan wells
29 reporting states, year-end 2023 (IOGCC)

An orphaned well has no solvent owner left to pay for plugging it, so the cost shifts to the state and its taxpayers. Every extra year a well stays profitable defers that bill and keeps its oil in production.

The bigger picture

Most of the wells, little of the oil

Marginal wells are about three quarters of U.S. producing wells but supply only about 5% of the country’s oil and gas. With so little volume per well, every recurring treatment and every day of downtime weighs on the margin.

~716,000
U.S. wells at or below 15 BOE a day
78% of producing wells (EIA, 2024)
~5%
of U.S. oil and gas supply from marginal wells
2023 data (RMI)
$47.6B
expected yearly cost of wax deposition to the oil and gas industry
range $14.7–330.6 billion (Sousa et al., 2022)

No national statistic separates paraffin and iron sulfide from the other reasons wells are plugged. But both are routinely listed among the causes of abnormal decline and high operating costs, and unlike a depleted reservoir, both can be treated at the cause.

Run your numbers. See what lower lifting costs and a slower decline mean for your own well: monthly profit, break-even, 7-year net profit and profitable life, with and without MEOR.

Stripper Well Profitability Calculator Fracked Well Profitability Calculator

Prove it on your own wells. A pilot on 3 to 10 wells puts your own numbers behind the economics on this page. Ask for a Well Data Sheet and we will write a proposal for your wells.

How a Production Pilot works Contact Hiltek

Sources for this section