How to Start an Oil and Gas Production Company

Starting an oil and gas production company means controlling mineral rights, capital, permits, and operating capability before you sell a single barrel. The order matters: leases and title first, then regulatory approval and bonding, then a technical team and field operation, then production accounting and risk management — and most new companies that fail skipped one of those steps rather than drilling a bad well.

Decide Whether You Will Operate or Own Working Interest

The first decision is not where to drill. It is whether your company will be the operator — the entity that runs the wells, holds the permits, files the reports, and carries the liability — or a non-operating working-interest owner that pays its share of costs and collects its share of revenue.

Operators need field capability, insurance, bonding, and a compliance function from day one. Non-operators need capital, a tolerance for cash calls, and the discipline to read joint operating agreements and authorization-for-expenditure documents before signing. A non-operator cannot tell the operator how to run the well and cannot simply stop paying its share when prices fall — non-consent provisions usually cost more later.

What a Non-Operator Actually Signs Up For

A joint operating agreement governs the relationship: who proposes wells, how expenditures are authorized, what happens when you elect not to participate, how overhead is charged, and how disputes reach audit or arbitration. Read the cost-sharing, lien, and abandonment clauses carefully; that is where most surprises come from.

Secure the Right to Drill: Land Work, Leases, and Title

Production begins with legal access to the minerals, not with equipment. In many areas the mineral estate has been severed from the surface, so the surface owner is not the person who can lease you the right to drill. You need a lease — or a working interest purchased from someone who holds one — and you need to know exactly what it says.

Lease terms that decide whether a project works:

• Royalty fraction and how it is calculated, including any deductions.
• Primary term, extension options, and what keeps the lease alive.
• Depth and formation clauses that limit what you are allowed to drill.
• Surface-use provisions, water rights, and road access.
• Pooling consent and continuous-development obligations.

Before you commit, run title. Courthouse records, probate files, and heirship questions decide whether a signature actually conveys anything. Unleased or unknown-interest tracts inside a spacing unit are common and can force you into a pooling hearing or a scramble to acquire leases.

Work the Regulatory Path Before You Move a Rig

Every producing state has an oil and gas regulatory agency that controls drilling permits, well spacing, bonding, and disposal. In Oklahoma, that agency is the Corporation Commission. You will need approval for the well, financial assurance, approved spacing and density, and separate authorization for saltwater disposal. Some of these are routine filings; others require notice to mineral owners and an administrative hearing.

Environmental obligations run in parallel: stormwater plans, air permits for tanks and compressors, spill prevention and response plans, and reporting on produced water. Skipping steps does not save time — it produces shut-in wells, penalties, and a compliance record that follows the company to its next permit application.

Build a filing calendar early. Permit expirations, production reports, and disposal volumes all carry deadlines, and a company that misses them can lose the right to produce.

Build the Technical Bench and the Field Operation

You need people who can read the rock and people who can keep iron turning. A geologist and a petroleum engineer — full time or contracted — evaluate offset production, decline curves, reservoir quality, and completion design. A landman handles leasing and title. A production superintendent or contract pumper watches daily rates, pressures, and equipment failures.

Most of the field work is done by service companies: drilling contractors, completion crews, workover rigs, roustabout crews, water haulers, and chemical treaters. The skill is in scoping and supervising them, not in owning every truck.

What Actually Drives Your Lifting Cost

Operating cost is set by artificial lift type and failure rate, how much water you must dispose of, chemical treating, electricity, road and pad maintenance, and how far produced fluids have to travel. A well that looks profitable on paper can turn marginal once water handling is counted properly.

Fund It, and Understand What Drives the Cost

Capital comes from equity partners, industry investors, reserve-based lending against proved reserves, and sometimes seller financing or vendor terms on equipment. The mix determines how much control you keep, how much debt service you carry, and how much pressure you feel when commodity prices move.

Anyone doing oil and gas investing wants the same things: a defensible reserve estimate, a realistic decline curve, honest lease operating expense, and clarity on price differentials and gathering costs. Bring those numbers, not a story.

Drilling and completion cost is driven by depth, lateral length, number of stages, proppant volume, and what services cost in the current cycle. Total project cost also includes acreage, roads and pads, gathering connections, and saltwater disposal. Ask what a dry hole or a failed completion costs, because that is the real downside you are underwriting.

Get Production Accounting and Compliance Right From the First Barrel

Once oil and gas flow, the paperwork multiplies. Division orders establish each owner's decimal interest; revenue statements distribute proceeds; joint interest billings collect costs from working-interest owners. Suspense accounts, escheat rules, and owner-relations questions surface quickly when titles are unclear.

Taxes and insurance are not optional. Expect severance or production taxes, property taxes on equipment and reserves, and reporting tied to volumes and values. On the risk side, control-of-well, pollution, general liability, and umbrella coverage protect the company from one bad day in the field.

Health, safety, and environmental programs need to be real, not binders on a shelf. Spill reporting, produced-water handling, and orphan-well rules are enforced, and a poor record makes it harder to buy properties, raise money, or sell the company later.

Scale, Hold, or Sell — and Who to Ask

A production company becomes durable when it is run as a portfolio. Rank every well by cash flow and remaining reserve rather than by how interesting it was to drill. Reinvest where returns justify it, distribute what the business does not need, and buy producing properties when they are cheaper than drilling comparable wells.

Keep records clean enough that a buyer can complete diligence without re-creating your history. Divesting non-core wells is normal, and a company that can document production, costs, and title will get better offers.

If you want to talk with an operator about how this work goes in Oklahoma, Silverton Energy Inc is a local oil and gas production company. They are open Monday through Friday, 8:00am to 6:00pm.

The sequence matters: land and regulatory control first, capital and people second, accounting and risk management from the first barrel onward. Skipping ahead rarely saves money.