The Coiled Tubing Unit: Equipment & Prices

A coiled tubing business is really a business built around one asset: the coiled tubing unit, or CTU. Everything in your plan, from the funding ask to the day-rate to the depreciation line, traces back to what that spread costs and how often it works. So the first substantive section of your business plan should be a hard equipment schedule, not a paragraph of prose. Lenders and equipment financiers want to see that you know what a spread is made of and what it is worth.

The core CTU is four things bolted onto a trailer or truck: the injector head that pushes and pulls the continuous coil in and out of the well, the coiled tubing string and its reel, the power pack (the hydraulic power unit that drives everything), and the control cabin where the operator sits. Around that core you assemble a pressure-control package and a fluid-pumping capability, because a bare CTU cannot service a live well on its own.

• Injector head: roughly $200,000 for the 80,000 lb model paired with 2-inch coil, and about $252,000 for the 100,000 lb model used with 2 3/8-inch coil. This is the part that fails jobs when it is under-spec, so do not cut here.
• Coiled tubing string: $150,000 for a small-diameter string up to around $300,000 for larger-diameter tubing. Coil is a consumable with a fatigue life, so budget for periodic replacement, not a one-off purchase.
• Reel: about $220,000, and the good news is the reel is reusable. When the string is retired you respool the reel with new tubing rather than buying a fresh reel.
• Power pack & control cabin: supplied as part of a complete unit build; the hydraulic power unit and cabin are what turn the injector, reel and controls into an operable spread.
• Complete CTU (trailer, injector, reel, power pack, cabin): $1.2M to $2.5M depending on pressure rating and coil size. A full 2-inch spread with all associated equipment can reach $4.5M to $5M; a 2 3/8-inch spread with everything can run $6.5M to $7M.
• High-pressure / fluid pump unit: needed for clean-outs, acid stimulation and circulating; twin fluid pumps and pump skids with integrated automation are standard.
• Blowout preventer (BOP) & wellhead pressure-control stack: non-negotiable safety equipment that lets you work over a live well.
• Nitrogen (N2) unit, fluid tanks, crane truck & tooling: the support fleet that determines which jobs you can actually mobilise for.

Component costs above are drawn from published equipment pricing (Prior Power Solutions, 2025). Put this schedule in your plan as a table, tie each line to a supplier quote, and your funding ask stops looking like a guess and starts looking like a purchase order.

What It Costs to Launch & How to Fund It

Once you total the CTU, the pressure-control package, the support fleet and the working capital to carry a crew through mobilisation, a single-unit independent coiled tubing operation lands somewhere between $1.4 million and $5 million in the US, or roughly £1.1 million to £4 million in the UK. The wide band is real: a lean, one-spread onshore operation working shallow wells sits near the floor, while a higher-pressure 2 3/8-inch spread with nitrogen and full stimulation capability sits near the ceiling.

Capital Breakdown

• Complete coiled tubing unit: $1.2M–$2.5M (£950K–£2.0M)
• Injector head (if bought separately / as a spare): $200K–$252K (£160K–£200K)
• Coil string + reel: $150K–$300K string plus ~$220K reel (£120K–£240K + ~£175K)
• Pump unit, BOP & pressure-control stack: $400K–$900K (£320K–£720K)
• Support fleet, crane truck, N2 unit, tanks, tools: $250K–$700K (£200K–£560K)
• Insurance bonds, certifications, 6 months working capital: $300K–$650K (£240K–£520K)

Funding Routes

Because the assets are large and titled, coiled tubing is one of the more financeable oilfield-service niches. In the US, SBA 7(a) loans reach up to $5 million with terms up to 25 years and are a natural fit for an operator with field experience and a signed or letter-of-intent client. Equipment finance and lease-to-own structures let you spread the CTU cost over its useful life so you are not tying up your whole raise in one trailer. Our bespoke plans build the SBA-format 5-year projections and the utilisation model lenders ask for.

In the UK, the government-backed Start Up Loan tops out at £25,000 per director and is best treated as founder working capital rather than the machine itself; asset finance and hire-purchase against the CTU carry the equipment. Similar asset-backed lending exists through the Business Development Bank of Canada (BDC) and, in the Gulf, through local equipment-leasing arms once you clear operator pre-qualification. If you also expect to pursue oil-storage or distribution adjacencies later, our oil refinery business plan template covers the capital logic for those heavier assets.

One financing nuance worth building into the plan: the CTU is titled collateral with a resale market, which lenders like, but the coil string and consumables are not. Structure your ask so the machine is carried by asset finance secured against the unit, while your equity and any SBA or working-capital facility cover the softer costs that a lender will not lend against, coil replacement, mobilisation, insurance premiums and the payroll runway that carries the crew until utilisation ramps. Getting that split right is often the difference between an approval and a decline, because it shows the lender you understand which parts of the business are bankable and which parts you have to fund yourself.

A second point that repeatedly comes up in review: the strongest plans model the first two to three years around a single spread and treat the second unit as a milestone triggered by proven utilisation, not as a day-one assumption. Adding capacity before you can keep the first unit busy simply multiplies fixed cost. Show the lender a conservative single-unit base case that stands on its own, then a clearly labelled expansion case, and you demonstrate the financial discipline that separates operators who survive their first downturn from those who do not.

Where Operators Buy Their Kit

Naming your equipment supply chain in the plan does two things: it proves you have priced the build with real vendors, and it reassures a financier that the collateral behind the loan comes from recognised manufacturers with a resale market. These are the names that recur across coiled tubing procurement:

• Prior Power Solutions – designs and builds hydraulic power packs, control cabins, high-pressure pump units and power hose reels for complete CT units.
• SERVA Group – fluid-pump products for CT operations, including single and twin fluid pumps and pump skids with integrated automation.
• Stimline Digital – manufactures injector heads, reel systems and complete coiled tubing units for both land and offshore operations.
• EnQuest Energy Solutions – parts, service, repair and upgrades, plus mast-style, yard-spooler, skid-, trailer- and truck-mounted CT units.
• NOV Inc. – a major original-equipment supplier across the well-intervention equipment stack.
• HydroSERV Technology – used and refurbished CT equipment, a route worth modelling if you want to lower the opening capital ask.

A practical point most first-time founders miss: whether you buy new or refurbished changes your whole funding story. A refurbished single-unit spread can pull the entry cost toward the bottom of the range, but it shortens the depreciation runway and can affect what operators will let on location. State the choice in the plan and defend it.

Certification & Compliance by Region

Coiled tubing is high-pressure work on live wells, so the licensing story is really a competency-and-safety story. You are rarely applying for a single trading licence; you are proving to operators and regulators that your crews and equipment meet recognised standards. Get this section right and you clear operator pre-qualification, which is the real gate to winning contracts.

United States

• OSHA oil & gas well servicing standards – well drilling and servicing is covered under 29 CFR 1910 general-industry rules, spanning lockout-tagout, fall protection, hydrogen sulphide, confined space and hot work (OSHA, 2026).
• API RP 54 – the industry recommended practice for occupational safety in oil and gas well servicing, widely required as part of operator vendor pre-qualification.
• IWCF or IADC WellSharp well-control certification – mandatory for crews in intervention work; roughly $1,000–$2,500 per person, renewed every two years.
• State oil & gas registration + DOT/FMCSA numbers – register with the relevant commission (for example the Texas Railroad Commission) and secure DOT authority to transport the unit.

United Kingdom

• HSE offshore safety regime – the UK Health and Safety Executive requires independent well examination of well design and operations, now a mandatory element of the offshore regime (HSE, 2026).
• BOSIET / FOET + offshore medical – every offshore crew member needs OPITO-approved offshore survival training (BOSIET around £900–£1,300) and an OEUK offshore medical.
• IWCF well control + LOLER/PUWER examination – well-control certification for crews plus statutory examination of lifting and pressure equipment on the CT spread.

Middle East (Saudi Arabia & UAE)

• Operator vendor pre-qualification – you cannot bid CT service work for Saudi Aramco or ADNOC without passing their vendor registration and HSE case approval first.
• Local content registration – IKTVA in Saudi Arabia and ICV in the UAE score in-country value; local partnership or sponsorship is typically required to trade.

Day-Rates, Utilisation & Margins

Coiled tubing revenue is a day-rate business with a utilisation problem. You do not sell a product; you sell your spread's time, and the number that makes or breaks the plan is how many days a year the unit is actually billing. A CTU sitting in the yard earns nothing while still burning insurance, financing and depreciation, so every serious CT business plan is built around a utilisation assumption you can defend.

In North America onshore, a single 2-inch CT spread bills roughly $18,000 to $45,000 per day depending on coil size, pressure rating, and whether the job needs nitrogen and fluid pumping. Offshore and high-pressure high-temperature work commands multiples of that. Most independents should model 150 to 220 billable days per year, not 365; mobilisation, weather, maintenance and the gap between contracts eat the rest.

Here is the arithmetic your plan should show. A single 2-inch onshore unit billing $28,000 per day at 180 utilised days generates about $5.04 million in gross revenue. After crew payroll (25–30% of revenue), coil replacement, fuel and nitrogen, insurance, maintenance and unit depreciation, an efficient independent nets roughly 8–12%, or about $400,000 to $600,000 on that one spread before financing costs. Add a second unit and the fixed overhead spreads, which is why the strongest plans lay out a path from one spread to two rather than pretending one unit is the whole business.

The service mix matters too. Well intervention and production is the workhorse: clean-outs, nitrogen lifts, acid stimulation, milling, fishing and logging on existing wells. That segment holds over 65% of the market, and it is where day-rate, repeat, relationship-driven revenue lives for a small operator. CT drilling is a different, more capital- and expertise-intensive line most independents grow into rather than launch with.

Coiled Tubing Market in 2026

The global coiled tubing services market sits between roughly US$7.5 billion and US$7.9 billion for 2025, and estimates converge on mid-single-digit growth through the decade. Mordor Intelligence puts the market at US$7.66 billion in 2025, reaching US$9.86 billion by 2030 at a 5.17% CAGR (Mordor Intelligence, 2025). Fortune Business Insights values it at US$7.54 billion in 2025, growing to US$10.45 billion by 2032 at a 4.69% CAGR (Fortune Business Insights, 2025).

Two structural facts shape where a new operator should aim. First, well intervention and production dominates: it holds over 65.4% of the market by service, and logging accounts for the largest operations share at around 20.6% (Market.us, 2024). Second, the market is concentrated: Schlumberger, Halliburton and Baker Hughes together hold roughly 60–65% of global share (BlackRidge Research, 2026). That concentration is the opening for independents, who win the shallow-well, workover and regional jobs the majors deprioritise.

Demand is concentrated where unconventional and shale activity is intensive, which is why North America is the deepest market for a first spread. But mature-field workover demand, where operators squeeze more production out of ageing wells, is durable through commodity cycles and is exactly the kind of steady, relationship-driven work a small CT business is built to serve.

Regionally, the Permian Basin in West Texas and New Mexico is the single deepest pool of onshore intervention work in the world, followed by the other US shale plays and the Middle East. The North Sea and other offshore basins pay far higher day-rates but demand offshore certification, a higher-spec spread and a heavier compliance burden, which is why most independents start onshore and grow toward offshore later, if at all. Your plan should be explicit about which basin you are targeting first and why, because a lender in Midland reads a Permian-focused plan very differently from a generic "North American oil and gas" pitch. Tie your utilisation assumption to real activity in your chosen basin, ideally with a nod to rig counts or workover activity, and the whole revenue model gains credibility.

Who Buys Coiled Tubing Services, and How Work Is Awarded

Your customer is not a consumer walking in off the street; it is a well operator, and understanding how that operator awards work is the single most valuable thing your business plan can demonstrate. Operators buy coiled tubing services in three broad ways, and a credible plan shows which of them you are built to win.

• Master service agreements (MSAs): the operator signs a framework contract with an approved list of service companies, then calls them off as wells need intervention. Getting onto that approved list is the whole game, and it depends on pre-qualification, HSE record and insurance, not just your day-rate.
• Call-out and spot work: smaller and mid-size operators, and larger operators with an urgent problem, hire on a per-job basis. This is where a responsive independent with a well-maintained spread and a nearby yard beats a major that has to schedule around its bigger commitments.
• Sub-contract to a larger service company: when a major is oversubscribed, it sub-contracts overflow to trusted independents. This can seed your utilisation in year one while you build direct operator relationships.

The strongest CT business plans segment their target market by well type and geography, not by vague buyer personas. A plan that says "we will target shallow, sub-8,000-foot vertical and horizontal wells within a 150-mile radius of our Midland yard, prioritising mature-field workover operators who value fast mobilisation" tells a lender exactly how revenue will be won. Contrast that with a plan that simply says "we will serve oil and gas companies," and it is obvious which one gets funded.

Pricing follows the same logic. Because the majors set a visible day-rate benchmark, independents rarely win on being the cheapest; they win on availability, responsiveness, safety record and the willingness to take the smaller jobs that a large service company treats as a nuisance. Your plan should make the case that your positioning defends a rate close to the market benchmark rather than a discount that erodes the thin net margin the sector already runs on.

Running the Spread: Operations, Crewing & Safety

A coiled tubing business lives or dies on operational discipline, and lenders know it, which is why the operations and HSE section carries real weight in a funding decision. The single asset is expensive, the work is high-pressure and hazardous, and a single serious safety incident can remove you from an operator's approved list overnight. Your plan needs to show that you have thought through the day-to-day realities, not just the headline economics.

Crewing and shift patterns

A single onshore spread typically runs a crew of four to six: a coiled tubing supervisor who owns the job on location, a unit operator who runs the injector and reel, two to three field hands, and a pump operator when the job calls for fluid pumping or nitrogen. On multi-day or 24-hour jobs you run two shifts, which roughly doubles the crew requirement. Because payroll is 25 to 30 percent of revenue, your crewing model and your utilisation model are two views of the same equation, and the plan should present them together.

Coil life and maintenance

The coiled tubing string is a consumable with a finite fatigue life measured in running feet and bending cycles. Every time the coil is spooled off the reel, run through the guide arch and gooseneck into the well, and pulled back, it accumulates fatigue. Serious operators track this per string and retire the coil before it fails downhole, because a parted string in a live well is a control incident, a fishing job, and a reputation problem all at once. Your financial model should carry a coil-replacement line, not treat the string as a one-time capital item, and your operations section should describe how you log and monitor fatigue.

Pressure control and well control

Working over a live well means the wellhead pressure-control stack and the blowout preventer are the difference between a routine job and a catastrophe. Crews carry IWCF or IADC WellSharp well-control certification, and operators audit your procedures during pre-qualification. A plan that names the certifications your crews hold, describes your safety-case documentation, and commits to third-party equipment examination signals to a lender that you understand the risk you are underwriting with their money.

Logistics and mobilisation

Mobilisation is dead time you pay for. Rigging up a CT spread on a well pad, pressure-testing, running the job and rigging down all take crew hours that are not always fully billable. The closer your yard sits to your target basin, and the tighter your logistics for coil, nitrogen and fluids, the more of the calendar you convert into billable days. This is why a specific base of operations, stated with its distance to target fields, belongs in the plan rather than a generic "we will operate regionally".

Coiled Tubing Terms Every Founder Should Use Correctly

Investors and lenders in energy services notice when a founder uses the vocabulary precisely. These are the terms that recur in a coiled tubing plan and what they actually mean:

• CTU (coiled tubing unit): the complete spread, comprising the injector head, reel and coil, power pack and control cabin, usually trailer- or truck-mounted.
• Injector head: the hydraulic drive that grips the coil and forces it into, or pulls it out of, a well against wellbore pressure. Rated by pull capacity, commonly 80,000 lb or 100,000 lb.
• Gooseneck: the curved guide arch that feeds coil off the reel and into the injector, controlling the bend radius that drives fatigue.
• Well intervention: any operation on an existing well to restore or improve production: clean-outs, nitrogen lifts, stimulation, milling, logging and fishing.
• Nitrogen (N2) lift: pumping nitrogen through the coil to lighten the fluid column and kick a dead or loaded well back into production.
• Fishing: retrieving lost or stuck tools and debris from a wellbore, a common and well-paid intervention task.
• Day-rate: the daily charge for the spread and crew, the primary revenue unit in the business.
• Utilisation: the share of the calendar the unit is actually billing; the number that most determines profitability.
• MSA (master service agreement): the framework contract that puts you on an operator's approved vendor list.

Five Ways CT Startups Burn Capital

These are the failure patterns we see most often when reviewing coiled tubing plans, and each one is avoidable with a sharper document.

• Buying the spread before the contract. A CTU is a two-million-dollar asset that earns zero until it is on a job. Lock a master service agreement or at least a committed operator client, or a strong letter of intent, before you draw down on the equipment.
• Modelling full-rate utilisation. Building the plan on 300-plus billable days is the single most common way founders overstate revenue. Model 150 to 220 days and let downtime, mobilisation and the gap between contracts show up in the cash flow.
• Ignoring coil fatigue life. The coil is a consumable. If your plan does not track running feet, cycles and fatigue-driven replacement, your maintenance line is fiction and your margins will not survive year two.
• Skipping operator pre-qualification. Without IWCF well control, API-aligned HSE processes and a clean safety case, you are locked out of the operators who actually award contracts, no matter how good your day-rate looks on paper.
• Under-scoping pumps and nitrogen. A bare CTU cannot bid half the jobs on offer. If you skimp on the pump unit, N2 capability and pressure-control stack, you narrow your addressable work before you have started.

More Questions Founders Ask

What is the difference between coiled tubing intervention and coiled tubing drilling?

Intervention runs a continuous coil into an existing well to service it, clean-outs, nitrogen lifts, acid stimulation, milling, logging and fishing, without pulling the completion. Drilling uses the coil to bore new or re-entry wellbores. Intervention and production is the larger, over-65% segment and the natural starting point for a new operator; drilling is more capital- and expertise-intensive.

Who are the largest coiled tubing service companies?

Schlumberger (SLB), Halliburton and Baker Hughes together hold roughly 60–65% of the global market. Other majors include Weatherford, NOV, Calfrac Well Services, Superior Energy Services and Calgary-based STEP Energy Services. The independent's edge is niche shallow-well, workover and regional work these companies do not prioritise.

How many people do you need to run a coiled tubing unit?

A typical single-spread crew is four to six: a CT supervisor, an operator, and two to three field hands, with a pump operator when the job needs fluid pumping or nitrogen. Payroll is one of your largest recurring costs, usually 25–30% of revenue, so your staffing plan and your utilisation plan have to be built together.

Is coiled tubing a good business to start in a downturn?

Workover and intervention demand is more resilient than new-drilling demand because operators still need to keep existing wells producing when commodity prices soften. A CT business focused on mature-field intervention can carry through cycles better than one built around drilling activity, which is worth stating explicitly in the plan's risk section.

Sample Business Plan Preview

Here is an extract from a coiled tubing business plan written by our team, so you can see the level of operational and financial detail lenders expect:

What's in the Template

Every Avvale business plan template is pre-structured for your industry. For coiled tubing, that means the sections a lender or equipment financier actually scrutinises:

• Executive Summary – the spread, the market, the day-rate and the ask, in a page that a credit officer can grasp in 60 seconds.
• Company Overview – legal structure, ownership, the founder's field track record, and base of operations.
• Equipment Schedule – the CTU line-items, injector, reel, pump, pressure-control, support fleet, tied to vendor quotes.
• Market Analysis – CT services market size, service-mix segmentation, and where your regional demand sits.
• Customer & Contract Analysis – target operators, master service agreements, and how work is actually awarded.
• Competitor Analysis – where the majors compete and the niche a single-spread independent can defend.
• Operations & HSE Plan – crewing, well-control certification, maintenance, coil fatigue tracking and safety case.
• Management Team – founder bio, key field hires and any advisory support.

The optional Financial Forecast add-on (included in the $300/£250 and $1,000/£800 packages) provides a 5-year Excel model built around utilisation and day-rate, with income statement, cash flow, balance sheet, break-even analysis and startup capital requirements. You can start from our free business plan template and upgrade when you are ready for the numbers.

Frequently Asked Questions