held by production, Oil & Gas Glossary

What Is Held by Production?

Held by production (commonly abbreviated HBP) is a lease status condition in which an oil and gas lease that has expired its negotiated primary term continues in force because the leased lands are producing hydrocarbons in paying quantities, as provided by the habendum clause of the lease. Once a lease is held by production, it remains valid indefinitely — without the payment of additional bonus or delay rental — as long as production in paying quantities continues or operations are being conducted on the leased premises. HBP is the most common mechanism by which operators maintain leases for decades beyond the original primary term, and it is a central concept in oil and gas title examination, lease brokerage, and acquisition due diligence.

Key Takeaways

The habendum clause in an oil and gas lease grants rights "for a term of X years and as long thereafter as oil and gas are produced" — the secondary term triggered by production is potentially infinite in duration.
"Paying quantities" is the legal standard for HBP: production revenues must exceed direct lifting costs, though courts also consider whether a prudent operator would continue operations given the realistic prospect of future profitability.
In a pooled or unitised spacing unit, production from a single well generally holds all acreage contributed to that unit, even tracts that have no wells of their own.
Cessation of production for longer than the permitted period in the lease — typically 60 to 90 days — may terminate the lease and result in automatic expiry of the lessee's rights.
Shut-in royalty clauses preserve HBP when a gas well capable of producing has no available market, allowing the lessee to maintain the lease by paying a nominal annual shut-in royalty payment to the lessor.

How the Habendum Clause Creates HBP Status

Every oil and gas lease contains a habendum clause — the "to have and to hold" language that specifies the duration of the grant. The standard formulation reads something like: "This lease shall remain in force for a primary term of three (3) years from the date hereof, and as long thereafter as oil, gas, or other minerals are produced from the leased premises or from lands pooled therewith, or operations for drilling are being conducted thereon." The primary term — one, three, five, or ten years depending on the vintage, jurisdiction, and negotiating leverage of the parties — gives the lessee time to evaluate the acreage and drill an initial well. Once production is established before the primary term expires, the lease transitions into its secondary term with no fixed expiration date. The lease is then said to be "held by production."

The "operations" savings language — allowing continued HBP when drilling operations are underway even if no production has been established — prevents a lease from expiring mid-well. What constitutes "operations" sufficient to extend the lease is frequently litigated; courts have generally required that the operator be actively and continuously working toward completion, not simply maintaining a wellhead or maintaining nominal activity. Some leases specify operations more precisely, requiring that a well be "being drilled" or "capable of producing" rather than merely "operations being conducted," and lease drafting on this point is a source of ongoing negotiation between landowners and operators.

Fast Facts: Held by Production

Abbreviation: HBP — used universally in title reports, lease schedules, and acquisition data rooms
Legal trigger: Production in paying quantities from the leased lands or from a pooled unit including those lands
Paying quantities standard: Revenue exceeding direct lifting costs; prudent operator standard may also apply
Cessation of production: Lease typically terminates if production stops for more than 60-90 days (varies by lease language)
Shut-in royalty: Annual payment (often $1-$10 per acre) to hold a gas well with no market without losing the lease
Pooling effect: One producing well holds all acreage in the pooled unit, including non-drilled tracts
Title work requirement: Landman must verify current production status and confirm unit boundaries in title opinion
HBP risk in unconventional plays: Shallow legacy wells may HBP deep rights that are uneconomic at shallow-well production rates

Field Tip:

When performing HBP title work on a large acreage package, never rely solely on a state production database to confirm HBP status. Databases often lag actual well status by 60-90 days. Instead, cross-reference the production database against the operator's own production records, and physically confirm that the production unit boundary encompasses the tract in question. A well showing "producing" status in the state database that was actually placed on a pump jack intermittently producing five barrels per day may or may not meet the "paying quantities" standard depending on the jurisdiction and the lease's lifting cost record — verify with the operator's LOE data.

Paying Quantities: The Legal Standard for HBP

Whether a lease is truly HBP depends on whether production meets the "paying quantities" standard, which is defined differently by statute, lease language, and case law across jurisdictions. The threshold test — production revenue exceeds the direct cost of lifting the oil or gas (operating expenses, or LOE) — is the floor. A well producing 0.5 barrels per day at a price of USD 70/bbl generates USD 35/day in gross revenue; if lifting costs (power, chemicals, disposal, labour) exceed USD 35/day, the well is not producing in paying quantities under this test. However, most courts apply a more nuanced "prudent operator" standard: even a temporarily unprofitable well may HBP the lease if a reasonably prudent operator, acting in good faith and in light of the prospects for future production, would continue to operate rather than abandon. This broader standard protects lessees from lease termination during temporary price downturns.

The paying quantities analysis becomes especially contested in unconventional plays where a vertical legacy well produces small volumes of conventional oil from a shallow formation while the same lease covers deep rights in a productive shale formation. A lessor may argue that the shallow well's production is inadequate to constitute paying quantities and that the lease should have expired, freeing the deep rights for competitive leasing. The lessee counter-argues that any profitable production, however small, satisfies the habendum clause. Courts in Texas, Colorado, and Oklahoma have generally sided with lessees where production is genuine and continuous, even at modest rates, provided lifting costs are demonstrably covered — but the litigation risk on marginal legacy wells HBP-ing high-value deep rights is real and should be assessed in any significant acquisition.

HBP by Pooling and Unitisation

Most oil and gas leases contain a pooling clause authorising the lessee to combine the leased acreage with adjacent tracts into a drilling or spacing unit, with production from any well in the unit deemed production from each tract in the unit. This pooling mechanism profoundly expands HBP coverage: a single well can hold dozens or even hundreds of individual lease tracts that make up the spacing unit, provided all tracts were validly pooled before the primary term expired. The pooling clause typically specifies a maximum unit size (often 40 or 80 acres for oil, 640 acres for gas) and requires formal pooling declarations to be recorded in the county records before production commences or the primary term expires.

Compulsory unitisation statutes in some states (Oklahoma, Louisiana) allow the relevant regulatory authority to force all mineral owners in a defined reservoir unit to participate in a unit, with production held proportionally across the unit. In these jurisdictions, a lessee can sometimes achieve HBP coverage over non-consenting tracts that would otherwise have expired, provided the regulatory unitisation order is obtained before the primary terms lapse. In jurisdictions without compulsory unitisation (notably Texas, for most formations), HBP by pooling requires each mineral owner's voluntary consent through the lease's pooling clause — a critical distinction when evaluating large acreage packages in multi-owner spacing units.

Held by production is also referred to as:

HBP — the standard abbreviation in all land, legal, and financial documents; used in drill schedules, acquisition memos, and division order work
held by operations (HBO) — a distinct but related status where active drilling or workover operations — rather than production — are extending the lease beyond its primary term under the operations savings clause
secondary term lease — describes a lease that has entered the indefinite secondary term; used interchangeably with HBP in some regional land practices

Frequently Asked Questions About Held by Production

What happens if production stops on an HBP lease?

Most leases contain a temporary cessation of production clause specifying that the lease does not automatically terminate if production stops for a period not exceeding a defined duration — often 60, 90, or 120 days — provided the lessee is diligently working to restore production. If production is not restored within the cessation period and no qualifying operations are underway, the lease terminates automatically by its own terms, with no requirement for the lessor to provide notice. The lessee loses all rights, and the mineral rights revert to the lessor. For this reason, operators in marginal fields often maintain minimum production rates — even at a loss — rather than risk lease termination during repair or workover operations.

How does a landman verify that a lease is genuinely held by production?

HBP verification requires four steps: (1) confirm that a valid pooling declaration or unit designation exists in the county deed records encompassing the subject tract; (2) verify in the state production database (Railroad Commission in Texas, OCC in Oklahoma, COGCC in Colorado, etc.) that at least one well in the unit reported production within the last reporting period; (3) obtain actual production records from the operator to confirm production occurred within the cessation-of-production period allowed by the lease; and (4) confirm that the production unit boundary, as recorded, includes the specific tract under examination. A title opinion that relies only on step 2 without steps 1, 3, and 4 is materially incomplete and may expose the acquiring party to title risk.

What are the implications of HBP for operators in unconventional shale plays?

In unconventional plays, vast acreage blocks are often held by production from legacy conventional wells drilled decades earlier, sometimes producing only a few barrels per day from shallow formations. The same leases typically cover deep shale rights that may be highly valuable but were uncontemplated when the lease was negotiated. Operators acquiring such acreage must assess whether the legacy HBP status is legally defensible — particularly if the shallow wells are producing at rates that might not satisfy the paying quantities standard — and whether the lease terms (royalty rate, depth severance clauses, pooling provisions) are acceptable for horizontal shale development. Lease depth severance provisions, if present, may allow the lessor to separately lease deep rights if the lessee is not developing them diligently, and this "horizontal Pugh clause" risk is a standard due diligence item in unconventional acquisitions.

Why Held by Production Matters in Oil and Gas

HBP status is one of the most consequential factors in determining the value and exploitability of an oil and gas acreage position. A lease that is HBP by robust, high-volume production from a well in the spacing unit represents a stable, indefinite right to drill the formation — a fundamental asset. A lease that is nominally HBP by a marginal legacy well producing at rates that may not satisfy paying quantities is a title risk that can erode acquisition values or block development financing. For landmen, petroleum engineers, and acquisition teams, understanding the nuances of HBP — the habendum clause, paying quantities standards, pooling mechanics, cessation of production traps, and shut-in royalty requirements — is essential to building and defending an acreage position in any active play.

Held by Production: Oil and Gas Lease Continuity Beyond Primary Term