SBA & Investor Funding Landscape for Directional Drilling Startups

Directional drilling is one of the few construction-adjacent trades where the SBA 7(a) loan programme is a genuine primary financing route rather than a last resort. The capital requirement is well within SBA limits, the collateral (drill rig + support equipment) is tangible and appraised, and NAICS code 213111 (Drilling Oil and Gas Wells) qualifies as a small business with up to 1,000 employees — covering virtually every independent operator in the market.

The SBA 7(a) programme allows borrowing up to $5 million for working capital, equipment, or real estate. For a typical single-rig HDD startup requiring $500,000–$700,000 in total capital, an SBA 7(a) loan covering 70–80% of that figure is achievable with a strong credit profile, a signed client contract or letter of intent, and a professionally prepared business plan with five-year financial projections.

What Lenders Want to See for NAICS 213111

SBA lenders who deal with oilfield services businesses have seen plenty of plans that list equipment and stop there. The plans that get approved address three things the lender actually cares about: revenue security, collateral value, and operator experience. Concretely, that means:

• Contracted revenue or a signed letter of intent — lenders treat unsigned "pipeline" as zero. Even a 60-day drilling contract from a regional E&P operator changes the risk profile dramatically.
• Equipment purchase agreement or verified auction quote — the rig and support equipment are the primary collateral. A professional appraisal or dealer quote is standard.
• Two to three years of personal tax returns — most HDD startups are sole proprietors or single-member LLCs before incorporation, so personal financial history is the lender's main credit signal.
• Operator certifications — IWCF or IADC Well Control for oil and gas directional work; a clean OSHA record (no willful violations) for utility HDD. These go into the management section of the plan.
• Five-year financial forecast — income statement, cash flow statement, and balance sheet. The cash flow model matters most: lenders want to see that debt service coverage ratio (DSCR) of at least 1.25x from Year 2 onwards.

Alternative Funding Routes

Equipment finance leases are common for newer operators who want to preserve working capital. Vermeer Financial and Ditch Witch Finance both offer manufacturer-linked lease programmes with competitive rates, and leasing removes the need to show a 20–30% down payment. The trade-off is that you do not build equity in the equipment and cannot use it as collateral for a subsequent loan.

In the UK, the Start Up Loans scheme (British Business Bank) provides up to £25,000 at 6% fixed with free mentoring — too small to fund a full HDD rig but useful for initial working capital, insurances, and permitting costs before larger asset finance is secured. The CBILS successor schemes and Growth Guarantee Scheme (GGS) allow up to £2 million for capital-intensive SMEs and are worth exploring for UK-based directional drilling startups targeting utility or infrastructure work.

For investors considering equity, this is a capital-intensive, cash-generative business with relatively predictable demand in infrastructure-heavy markets. The pitch should centre on contracted day-rate visibility, barriers to entry (equipment cost + certification), and the infrastructure spending backlog driven by broadband rollout and pipeline replacement programmes on both sides of the Atlantic.

The Directional Drilling Services Market in 2025–2026

The global directional drilling services market was valued at approximately $13.87 billion in 2025 and is projected to reach $25.07 billion by 2034, growing at a CAGR of 6.65% (Fortune Business Insights, 2025). A parallel estimate from Cognitive Market Research puts the 2024 figure at $18.5 billion, with a projected $32.5 billion by 2032 at a 6.45% CAGR — the variance reflects different market scope definitions (oil and gas only vs. oil, gas, and utility HDD combined).

North America is the dominant region, capturing approximately 36.8% of 2024 global revenue. Within North America, the Permian Basin alone accounts for roughly 60% of US land drilling activity. The shale revolution made directional drilling a permanent feature of oil and gas extraction — virtually no commercially viable unconventional well can be drilled without a directional component. On the utility and infrastructure side, demand is driven by broadband fibre rollouts, water main replacements, and gas distribution upgrades, all of which require trenchless crossing solutions.

Asia-Pacific is the fastest-growing regional market, driven by accelerating offshore development in Southeast Asia and onshore gas expansion in Australia and China. Europe's market is more modest in absolute size but provides steadier, regulatory-driven work — gas network decommissioning and replacement in the UK and Germany, offshore decommissioning in the North Sea, and fibre-to-premises programmes across the EU.

Market Segmentation: Oil & Gas vs. Utility HDD

The directional drilling market splits into two distinct service categories that share technology but differ sharply in client type, contract structure, day rates, and entry barriers.

Oil and gas directional drilling involves steering wellbores to hit reservoir targets at depth. Operators include Schlumberger (SLB, approximately 32% global market share), Halliburton (17%), and Baker Hughes (13%), but below those three is a large market of independent directional drilling companies — in Texas alone, the major four players combine for only 16% of total footage drilled, with the rest going to independents and private equity-backed operators (SPE Journal of Petroleum Technology). Day rates for a directional driller in oil and gas run $8,000–$25,000 per day depending on well complexity.

Utility and infrastructure HDD is the trenchless-construction segment: fibre broadband, water mains, gas distribution pipelines, sewer crossings, and river crossings. Day rates are lower — $2,500–$8,000 per day — but the market is broader, clients are more diverse, and the barrier to entry is lower. Most HDD startups enter through utility work before moving up to larger pipeline and oil-and-gas contracts.

Demand Drivers Through 2030

• Shale and unconventional gas expansion: US shale production from the Permian, Marcellus, and Utica plays continues to grow; every new lateral requires directional services.
• Broadband fibre rollouts: The US Infrastructure Investment and Jobs Act allocated $65 billion for broadband — a large share will be delivered through trenchless HDD in rural areas. UK's Project Gigabit similarly drives utility HDD demand.
• Aging pipeline replacement: The US has over 2.5 million miles of gas pipeline; the EPA and PHMSA are accelerating replacement of older distribution mains, most of which cross roads and cannot be open-cut.
• Offshore decommissioning and tie-backs: North Sea operators are drilling directional sidetrack wells to access remaining reserves from existing infrastructure rather than drilling new wellbores.

Capital Requirements: What It Actually Costs to Start

Starting a directional drilling company is a capital commitment comparable to opening a small manufacturing facility. The numbers that circulate online — "you can start for $90,000" — refer to the absolute bare minimum: a single small utility rig with no support equipment, no mud system, and no working capital buffer. A viable single-rig operation that can tender for real contracts typically requires $300,000 to $830,000 in total startup capital (£240,000–£660,000 in the UK).

The breakdown that follows is based on published equipment pricing from major HDD rig manufacturers and operators' cost disclosures from publicly available industry sources.

Equipment: The Core Capital Outlay

• HDD drill rig — $150,000–$400,000 (used): The rig is the centre of the operation. For utility work, a Vermeer D24x40 or Ditch Witch JT25 covers most residential and light commercial bores. Moving into larger utility crossings or pipeline work requires a Vermeer D100x140 or similar, which costs $250,000–$400,000 used. Brand-new mid-size rigs from Vermeer Corporation or The Charles Machine Works (Ditch Witch's parent) run $350,000–$600,000.
• Vacuum excavator + truck + trailer — $135,000–$200,000: The vacuum excavator pothole utilities ahead of the bore path and removes drilling slurry. Without it, you cannot safely work near live utilities. This is the part of the kit most first-time operators underestimate.
• Mud mixing and recycling system — $20,000–$60,000: Drilling fluid (bentonite mud) is critical for bore-hole stability and pipe lubrication. A basic mixing system costs $20,000; a closed-loop recycling unit that reduces waste and environmental risk runs $40,000–$60,000.
• Locating system (MWD/walkover) — $20,000–$60,000: For utility HDD, a walkover locating system like the DigiTrak Aurora or Subsite 750T costs $20,000–$35,000. Oil and gas directional work requires wireline MWD (measurement while drilling) tools, which are typically rented from suppliers at $400–$800/day rather than purchased outright for a startup.
• Drill pipe, housing, tooling — $15,000–$40,000: Consumable tooling — bits, reamers, housing stems — adds up quickly. Budget $15,000 for a light utility setup; $40,000 for a full kit covering different ground conditions.

Pre-Revenue Costs

• Commercial general liability insurance — $15,000–$30,000/year: Most general contractors and utility operators require $2M–$5M CGL coverage before you can mobilise on their sites. Workers' compensation adds another $8,000–$18,000 annually depending on payroll size and state rates.
• Contractor licenses and permits — $5,000–$15,000: State contractor registration, any required bonding, initial drilling permits, and OSHA 10/30 cards for the crew. Budget higher if working in California, New York, or other high-regulation states.
• Working capital (3 months) — $50,000–$80,000: Covers crew wages, fuel, mud consumables, and equipment maintenance before invoices are paid. HDD clients typically pay on 30–45 day terms; startup operators often have no credit terms with suppliers, so the working capital requirement is front-loaded.

US vs. UK Cost Comparison

UK equipment costs track US prices closely because the global HDD rig market is dollar-denominated — Vermeer and Ditch Witch export globally at roughly equivalent sterling values. The meaningful cost differences in the UK are: higher insurance premiums (public liability minimum £5M for street-works projects), more expensive permitting under the New Roads and Street Works Act 1991 (NRSWA), and higher labour costs in the South East. A single-rig utility HDD setup in the UK runs £240,000–£660,000, with the upper end reflecting London-area operating rates.

Funding Routes Summary

• SBA 7(a) loan (US): Up to $5M; equipment and working capital eligible; NAICS 213111 qualifies; 10-year term typical for equipment loans.
• Equipment lease finance (US/UK): Vermeer Financial and Ditch Witch Finance offer manufacturer-linked leases; preserves working capital but no equity in equipment.
• USDA Business & Industry loan (US rural): Relevant for operators setting up in rural shale regions; up to $25M; longer terms than SBA.
• Growth Guarantee Scheme (UK): Up to £2M; 70% government-backed; suitable for UK utility HDD operators with a contracted revenue base.
• Start Up Loans (UK): Up to £25,000 at 6% fixed — covers initial insurance and permitting costs for a UK HDD startup.

Revenue Model, Day Rates, and Worked Unit Economics

Directional drilling revenue is built almost entirely on two billing structures: day-rate contracts and footage-based contracts. Understanding which applies and how margins behave in each is the core of any credible financial model.

Day-Rate Contracts

Under a day-rate contract, you charge a fixed daily fee regardless of footage drilled. The client bears the geological risk — if you hit unexpectedly hard rock and progress slows, the day rate continues. Day rates for a small utility HDD rig run $2,500–$8,000 per day. Oil and gas directional work commands higher rates: $8,000–$25,000 per day depending on well complexity, depth, and region. For context, Patterson-UTI Energy, one of the largest public land drillers in the US, reported average US drilling rig revenue of $35,290 per operating day with an adjusted gross profit of $15,720 per day in Q4 2024 — margins that reflect the scale and sophistication of their operations, not a realistic benchmark for a startup but a useful ceiling to model against.

Footage-Based Contracts

Under a footage-based contract, you charge per linear foot drilled — typically $20–$80 per foot for utility HDD depending on diameter, depth, and ground conditions. Rock formations and congested utility corridors command the higher end; sandy soils at shallow depths are priced near the floor. The operator bears the geological risk in a footage contract. Experienced HDD contractors often prefer footage billing in ground they know well (faster progress = more income); clients prefer footage billing because the budget is more predictable.

Worked Unit-Economics Example — Single Utility HDD Rig

The following is an illustrative model for a single-rig utility HDD operation in a mid-size US market (composite estimate; actual figures will vary significantly by region, ground conditions, and contract mix):

Cost breakdown on $1.1M gross revenue:

• Crew wages (3 FTEs at ~$112,000 avg): $336,000 — operator, locator, and field labourer. BLS SOC 47-5012 (Rotary Drill Operators, Oil and Gas) median annual wage is approximately $67,000, but experienced directional drillers command $95,000–$130,000 in tight labour markets. Average across the crew at $112,000 is consistent with Glassdoor and Salary.com data.
• Equipment depreciation (rig + support): $55,000 — based on $550,000 total equipment value depreciated over 10 years straight-line.
• Fuel, mud, tooling consumables: $75,000 — approximately $375 per operating day; higher in rock drilling.
• Insurance (CGL + workers' comp + tools): $28,000 — annual commercial general liability and workers' compensation at standard rates for a 3-person construction crew.
• Equipment finance interest: $35,000 — approximate annual interest on a $400,000 SBA equipment loan at 8.5% over 10 years.
• Overhead (admin, software, professional fees, vehicle): $65,000 — includes accounting, OSHA compliance, permits per project, and basic office costs.
• Total costs: $594,000
• Net income before tax: ~$506,000 on gross revenue of $1.1M — approximately 46% operating margin. Effective net margin after principal repayment and owner draw is typically 15–22%.

The numbers above assume consistent utilisation. The biggest margin risk in HDD is idle days — a rig sitting in the yard costs money (insurance, depreciation, loan interest) whether it is running or not. Operators who maintain 80%+ utilisation by mixing oil and gas work (higher day rates, longer mobilisations) with utility work (lower rates, shorter jobs, steadier pipeline) typically achieve the strongest economics.

Additional Revenue Streams

Beyond core boring, a directional drilling business can generate ancillary revenue from: equipment rental to smaller operators (a spare locating system generates $150–$300/day with no labour cost); pipe supply and product supply on footage contracts; and training/certification services as the operator becomes established. None of these replaces drilling revenue, but they improve asset utilisation and smooth cash flow during drilling slow seasons.

Workforce Costs: BLS Data for Directional Drilling Operations

Labour is typically the second-largest cost after equipment finance in a single-rig HDD operation, accounting for 25–35% of gross revenue. Getting the staffing model right in a business plan — rather than using generic construction wage benchmarks — is the difference between a financial model that lenders trust and one that gets sent back for revision.

BLS Occupational Data — Key Roles

The Bureau of Labor Statistics tracks two occupational codes directly relevant to an HDD business plan:

SOC 47-5012 — Rotary Drill Operators, Oil and Gas: This code covers operators who set up and operate drilling equipment for oil and gas extraction, which includes directional drilling crew leads. BLS 2023 data (the most recently published full-year figures) shows a median annual wage of approximately $67,000, with the 90th percentile reaching $109,000+. In tight labour markets like the Permian Basin, the Bakken, and the Marcellus, experienced directional drillers regularly command $95,000–$130,000 annually. Glassdoor directional driller data (2026) puts the national average at $112,462/year — consistent with on-the-ground market rates. Total employment in this SOC is approximately 20,000 workers nationally, and demand is cyclical with oil prices.

SOC 47-5011 — Derrick Operators, Oil and Gas: Locators and second-position crew members on HDD rigs typically fall into this or adjacent codes. BLS median wage is approximately $58,000–$65,000 annually. Entry-level HDD labourers (ground support, mud mixing) typically start at $38,000–$45,000 before progressing to locator roles.

UK Workforce Costs

In the UK, directional drilling operatives are typically employed through the Construction Industry Training Board (CITB) registered contractors. Pay scales for HDD operators in the UK run approximately £35,000–£65,000 depending on experience and location, with North Sea directional drilling specialists earning significantly more under offshore rotation contracts (£80,000–£120,000+ for senior MWD engineers). CITB levy applies to UK construction contractors with an annual payroll above £120,000, adding approximately 0.35% of payroll in annual levy costs.

Staffing Structure for a Single-Rig Startup

• Directional driller / rig operator (1 FTE): $95,000–$130,000 US / £45,000–£65,000 UK. The owner-operator often fills this role in a startup, which is the primary way to keep early-stage labour costs manageable.
• Locator / second-position operator (1 FTE): $65,000–$85,000 US / £35,000–£50,000 UK. Critical for all surface HDD work; cannot be eliminated.
• Ground support labourer (1 FTE or sub-contract): $40,000–$55,000 US / £28,000–£38,000 UK. Often day-hired or subcontracted for smaller jobs, improving flexibility.

A business plan should model two scenarios: owner-as-operator (lower Year 1 labour cost, limited scalability) and fully hired crew (higher fixed cost, better scalability). Lenders will want to see both — and they will typically base their DSCR calculation on the hired-crew model as a conservative case.

Licensing, Permits & Regulatory Requirements by Jurisdiction

Regulatory requirements for directional drilling are more complex than most construction trades because the work spans multiple regulatory frameworks simultaneously: construction safety law, environmental law, utility protection law, and (for oil and gas work) energy sector law. The plan must address all applicable layers — a lender or investor reviewing a directional drilling business plan will flag any jurisdiction where compliance has not been addressed.

United States

• NAICS 213111 contractor registration: Register your business entity and obtain a state contractor licence in the states where you will operate. Many states require a specific pipeline or drilling contractor endorsement in addition to a general contractor licence. Fees range from $200–$2,000 per state.
• State oil and gas drilling permit: Required for all oil and gas directional wells. Issued by the relevant state commission — Texas Railroad Commission (RRC), Colorado Energy and Carbon Management Commission (ECMC), North Dakota Industrial Commission (NDIC), etc. Permit fees: $500–$5,000 per well; timeline: 2–8 weeks from complete application.
• OSHA 29 CFR 1926 (Subpart P — Excavation and Trenching): The primary federal safety standard for all HDD work. Crew leads should hold OSHA 30-hour construction cards; site supervisors should be Competent Persons as defined under Subpart P. Non-compliance penalties: up to $15,625 per violation, $156,259 for willful violations.
• DOT/PHMSA 49 CFR Part 195 — Pipeline crossing notification: Mandatory 14-day advance written notice to the pipeline operator when boring within 25 feet of a regulated pipeline. Non-compliance creates liability exposure exceeding $1 million per incident.
• 811 — Call Before You Dig: Mandatory minimum 3 business days advance notice before any excavation. Every state participates; non-compliance voids insurance cover in most policies.
• IWCF / IADC Well Control certification: Required for all personnel working on oil and gas wells under most operator well control programmes. Two certification bodies: IWCF (International Well Control Forum) and IADC (International Association of Drilling Contractors). Cost: $800–$2,000 per person; timeline: 3–5 days of training and examination.

United Kingdom

• NSTA Well Operations Consent (WONS) — oil and gas: Any directional well operation on the UK Continental Shelf or onshore (England) requires consent from the North Sea Transition Authority using the WONS system. Applications are made via the NSTA Energy Portal; a minimum 28 days notice is required once all documentation is submitted. The NSTA coordinates with HSE and the Environment Agency.
• HSE HSG47 compliance — underground services: The HSE's guidance book Avoiding Danger from Underground Services (HSG47) sets out the mandatory planning and detection process for all HDD work near utilities. This is not a licence but an enforced standard — non-compliance is prosecutable under the Health and Safety at Work Act 1974.
• New Roads and Street Works Act 1991 (NRSWA) — Section 50 licence: Required for any HDD bore in the public highway (roads, pavements, cycleways). Applied for through the local highway authority. Fee: approximately £400–£2,000 per project depending on traffic management requirements; advance notice: minimum 7 days (Section 54 minor works; major works require 3 months notice).
• HAUC SROH — highway reinstatement: Any surface break (even minimal for a cable or product pull) must comply with the Specification for Reinstatement of Openings in Highways (SROH). Inspection fees: £100–£500 per excavation.
• CITB registration and levy: If your payroll exceeds £120,000, CITB levy applies at 0.35% of total payroll. Registration is free and gives access to CITB training grants.

Australia

Australia has no national licensing requirement for HDD operators, but project-level approvals are mandatory. Council or road authority permits are required for any work in the road reserve. In Queensland, design elements (bore path, support equipment placement) must be certified by a Registered Professional Engineer of Queensland (RPEQ) with HDD experience. The RIINHB323D unit of competency (Horizontal Directional Drilling) is not legally mandated but is expected by most utility clients as a Verification of Competency (VOC). Environmental approvals are required for any bore crossing a waterway.

Canada

Road Occupancy Permits (ROP) are required from the relevant provincial highway authority for any bore under a public road. Municipal Consent (MC) permits are typically managed by the client's engineer on utility projects. Environmental assessment is required for crossings of navigable waterways under the Navigation Protection Act. For oil and gas directional work, the relevant provincial energy regulator (Alberta Energy Regulator, BC Oil and Gas Commission, Saskatchewan Ministry of Energy) issues well permits. The OMNIA Training 9-week HDD Operator certification programme is the industry-standard entry credential for Canadian utility HDD operators.

5 Costly Mistakes in Directional Drilling Business Plans

Most of the mistakes in directional drilling business plans are not writing problems — they are knowledge problems. The plan looks complete until someone who actually runs an HDD crew reads the staffing budget or the mobilisation timeline. Here are the five that appear most often in plans we review:

1. Treating the Rig as the Total Equipment Budget

The rig is roughly half the capital cost of a functioning HDD operation. A $200,000 rig with no vacuum excavator, no mud system, no locating equipment, and no tooling cannot mobilise on a real project. Most first-time operators budget for the rig and then discover the support kit at the equipment dealer. The business plan should itemise all equipment in a startup cost schedule — lenders who see "rig: $200,000, other equipment: $20,000" know immediately that the operator has not been in the field.

2. Accepting Fixed-Price Footage Contracts Without a Ground Survey

Footage-rate contracts are attractive in soft ground — progress is fast, income per day is high. In rock, unidentified clay layers, or congested utility corridors, a footage-rate bore can lose $10,000–$30,000 in a single day. Operators who submit footage-rate bids without a Phase 1 geotechnical assessment or at minimum a utility-corridor scan are taking on geological risk that cannot be modelled in a financial plan. The plan should describe your pre-bid assessment protocol; lenders and investors expect to see this.

3. Skipping Pre-Bore Utility Locates (811/HSG47)

Striking an unmarked utility is the most common catastrophic event in HDD. In the US, a natural gas strike carries a minimum cleanup and third-party liability of $200,000–$500,000. Striking a fibre optic cable serving a data centre can trigger $1M+ in consequential damages. Both the 811 system in the US and HSG47 guidance in the UK require advance notification and on-site potholing before boring in utility-dense corridors — these are not optional. A business plan that does not show a formal pre-bore locate protocol will not satisfy a commercial insurance underwriter, let alone an SBA lender.

4. Modelling 250+ Operating Days in Year 1

A single-rig HDD operation typically achieves 160–200 billable days in Year 1 — not 250. Weather downtime, equipment commissioning, contract mobilisation gaps, crew availability, and permit delays all reduce utilisation. Financial models that assume 230–260 days produce revenue projections 15–30% above what is achievable. Use 170–185 days for Year 1, 190–205 for Year 2, 200–220 for Year 3 as a conservative planning assumption. Most SBA lenders apply a 15–20% stress test to revenue projections anyway; starting from a realistic number means you pass the stress test rather than fail it after the cut.

5. Omitting Crew Certification Costs and Timelines from the Pre-Revenue Budget

IWCF Well Control certification costs $800–$2,000 per person and requires 3–5 days off-site. OSHA 30-hour cards take four days. State contractor licence applications can take 8–12 weeks. None of these can be skipped on oil and gas projects, and several cannot be expedited. A startup that plans to mobilise six weeks after equipment delivery without accounting for crew certification and licensing timelines will miss its first contract. The pre-revenue cost schedule in the business plan should include all certification costs and a realistic timeline that accounts for application wait times.

Sample Plan Extract: Apex Directional Drilling LLC

Here is an extract from a directional drilling services business plan written by the Avvale team, showing the executive summary format and financial summary structure we use for SBA 7(a) and investor submissions:

What the Directional Drilling Business Plan Template Includes

Every Avvale business plan template is structured for the specific operational reality of the niche — not a generic framework with the industry name swapped in. For directional drilling services, the template includes:

• Executive Summary — Written to lead with the funding ask, the contracted revenue anchor, and the operator's field credentials — the three things a drilling-industry lender reads first.
• Company Overview — Legal entity structure, ownership, location, NAICS code, and founding narrative. Includes guidance on LLC vs. S-Corp structure for a contractor business.
• Industry Analysis — Market sizing (oil and gas directional vs. utility HDD segments), demand drivers, major competitor analysis (SLB, Halliburton, Baker Hughes, regional independents), and the market opportunity for independent operators.
• Customer Analysis — Target client types: E&P operators, utility contractors, municipalities, general contractors. Buying criteria, contract structures, and how to approach each segment in the sales cycle.
• Operations Plan — Rig mobilisation protocols, pre-bore procedures (811/HSG47), crew structure, bore-log documentation, and equipment maintenance schedules. This section is what oilfield-experienced lenders look at hardest.
• Marketing & Sales Plan — How to build a contract pipeline: E&P AFE timing, general contractor bid invitation lists, utility provider approved-vendor applications, and the role of equipment-dealer referral networks.
• Management Team — Operator certifications (IWCF/IADC), OSHA credentials, field experience summary, and advisory board if applicable.
• Risk Analysis — Commodity price risk (for oil and gas work), utilisation risk, liability exposure scenarios, and insurance strategy. Lenders in the energy services space require explicit risk discussion.

The optional Financial Forecast (included in the $300/£250 and $1,000/£800 packages) adds a five-year Excel model with: startup capital schedule, monthly cash flow (Year 1), annual P&L and balance sheet (Years 1–5), break-even analysis at multiple day-rate and utilisation assumptions, and DSCR calculation for SBA lender review.

Related templates that may be relevant to your planning: Drilling Services Business Plan Template and Offshore Drilling Rigs Business Plan Template cover adjacent segments where client overlap is common.

Frequently Asked Questions

Related Business Plan Templates & Resources

If your directional drilling business overlaps with adjacent segments or you need supporting materials, these Avvale resources are relevant:

• Drilling Services Business Plan Template — broader drilling services including cable tool and rotary drilling.
• Well Drilling Business Plan Template — water well and geothermal well drilling operations.
• Offshore Drilling Rigs Business Plan Template — for operators targeting North Sea and Gulf of Mexico offshore contracts.
• Free Business Plan Templates — full library of free downloads across all sectors.
• Business Plan Writer Service — our consulting team writes the whole plan for you.
• Client Case Studies — real (composite) examples of funded plans across energy and engineering sectors.