Oklahoma City Energy Services: 7 Debt Moves Starting With the Lien You Never Filed

What an Oklahoma Service Company Owns Before It Owes Anybody

A well servicing company three or four advances deep usually believes it holds two assets, a fleet and an aging report, and that the restructuring ahead is a negotiation about how much of the aging report the funders will accept. That framing costs real money in this state. Oklahoma has since statehood given anyone who performs labor or furnishes machinery for the drilling, completing, operating or repairing of a well a lien on the leasehold, on the well, on the equipment standing on it and on the proceeds of the oil and gas it makes, and that lien is a materially different asset from the invoice it secures. In the files we work, most Oklahoma service companies have never filed one.

The reason is ordinary and it is not stupidity. Filing against the operator that dispatches your workover rig every month feels like ending the relationship, so the 180-day clock in 42 O.S. §146 runs quietly while a controller explains that the joint interest billings are about to clear and the gas check is late from the purchaser. By the time somebody calls a settlement desk, the receivables that were supposed to fund the settlement have gone unsecured, and on the older wells they are past the filing window entirely. Nobody on the funding side is confused about any of this, because they filed their financing statements the week they funded.

There is a second half almost nobody explains, which is that the same statutes cut in both directions at once. Your funder’s UCC-1 reaches your accounts, and one of those accounts may itself be secured by a statutory lien on a producing leasehold and by an automatically perfected claim on production proceeds that Oklahoma law ranks ahead of security interests generally. What a receivables buyer actually purchased is worth whatever the operator can be made to pay, and what the operator can be made to pay turns on paper that you either filed inside the statutory window or did not file at all.

Everything below is Oklahoma law read out of the statute books and the opinions, priced from the other side of the table. Take the concession first, because it decides whether the rest is worth your week. A lien does not manufacture money out of an operator that has none, several of these claims lose outright to a bank mortgage recorded before your crew ever rigged up, and the company whose name is on the work order is frequently not a company you can collect a dollar from. Working out which of those describes your file is the entire exercise, and it takes a title search and a calendar rather than an opinion.

1. The Lien Relates Back to the Day You Rigged Up

Title 42, Section 144 gives any person, corporation or copartnership that performs labor or services, or furnishes material, machinery and oil well supplies used in the digging, drilling, torpedoing, completing, operating or repairing of any oil or gas well, under an express or implied contract with the owner of a leasehold for oil and gas purposes, or with that owner’s trustee or agent, a lien. The verbs are worth reading slowly, because completing, operating and repairing sit in the same list as drilling, which puts a workover crew, a swab rig, a roustabout gang building location, and a company hauling produced water under a service contract inside the same section as the drilling contractor. Section 145 extends the identical lien, in the same manner and to the same extent, to anyone furnishing machinery or supplies to a subcontractor and to an artisan or day laborer in a contractor’s employ.

What the lien attaches to is unusually generous by the standards of American lien statutes. Section 144 impresses it on the whole of the leasehold, the buildings and appurtenances, the material and supplies furnished, the oil well supplies, tools and other articles used on the well, the well itself, all other fixtures and appliances used in operating for oil and gas purposes on that leasehold. It reaches, on top of all of that, the proceeds from the sale of oil or gas produced from that leasehold inuring to the working interest, with valid bona fide reservations of oil or gas payments and overriding royalty interests executed in good faith carved out of the proceeds half. Section 146 then fences the real property side: the lien affects only the oil and gas leasehold estate and does not otherwise reach any other interest in the land, except that where a mineral owner also holds a working interest in a well located there, it attaches to that working interest.

The clocks come out of Section 146 and they are not the construction clocks that Oklahoma contractors are trained on. The statement goes to the county clerk of the county where the land sits, within 180 days after the date material, machinery or supplies were last furnished or labor or services last performed under the relevant contract or subcontract. That is a longer runway than the four months §142 gives a building contractor, or the ninety days §143 gives a building subcontractor. Section 146 also states in terms that §142.6 does not apply to these liens, so the seventy-five-day pre-lien notice that quietly kills so many construction claims is simply not a trap out here. Section 143.1 has the county clerk mail notice by certified mail, return receipt requested, within five business days of filing, off the addresses you supply, and §172 requires the foreclosure suit within one year of the filing date.

The catch is who you can actually collect from, and the Oklahoma Supreme Court drew that line hard in K & H Well Service, Inc. v. TCINA, Inc., 2002 OK 62, 51 P.3d 1219. K&H reworked two wells in Seminole County, went unpaid, filed its lien statements and sued, and the contract operator that had hired it walked away clean, because it was the agent of disclosed principals and owned no leasehold interest in the lands the lien covered, while judgment and foreclosure ran instead against a holding company carrying a recorded five percent interest in the leases. The court did rescue the lien from an attack on its legal description, holding that substantial compliance is met where the description would let a person familiar with the property identify the premises or would put the named party on inquiry notice, and confirming that a conforming lien relates back to the date work was first performed on the job site.

2. The Certified Letter That Reaches the Crude Purchaser

The half of §144 that almost nobody uses is the lien on production proceeds, and Oklahoma gave it a separate step that has nothing to do with the courthouse. Under 42 O.S. §144.1, no lien claimed under the act, insofar as it extends to the proceeds from the sale of oil or gas produced from the lease, is effective against any purchaser of that oil or gas until a copy of the statement of lien claim has been delivered to that purchaser by registered or certified mail. Filing with the county clerk and mailing to the first purchaser are two different acts aimed at two different parties, and doing only the first leaves you holding a claim against a leasehold estate while the monthly revenue keeps flowing past you into the account of the operator that is not paying you.

What the second act does is visible in the record of the largest Oklahoma case ever litigated under this statute. In the White Star Petroleum bankruptcy in the Western District of Oklahoma, seventy-eight unpaid vendors filed adversary proceedings asserting §144 liens. The debtor then had to commence a proceeding of its own, asking the court to order several first purchasers of oil and gas to turn over roughly two million dollars the purchasers were holding in suspense after receiving statutory lien notices from those claimants, facts the Oklahoma Supreme Court recites in White Star Petroleum, LLC v. MUFG Union Bank, N.A., 2020 OK 89, 480 P.3d 887. A purchaser suspends in order to avoid paying for the same barrel twice, which is a self-interested act that happens to work in your favor.

From the operator’s side of the table a suspended revenue stream is a completely different problem from an aged payable, and it gets escalated on a different timetable, which is the entire point of sending the letter. The operator also has a way out that you should understand before you file rather than after it. Under 42 O.S. §147.1 a property owner, a mortgagee, a contractor or any other interested party may discharge the lien at any time by depositing with the county clerk either cash equal to 125 percent of the lien claim or a corporate surety bond with a penal amount equal to 125 percent of the claim, which clears the record while preserving your claim against the deposit. A well-advised operator often prefers exactly that, and for you it is a substitution of a funded obligation for an unsecured invoice.

Two practical limits sit on the move. You have to know who the first purchaser is, which 52 O.S. §549.2(4) defines as the first person that purchases oil or gas from an interest owner, directly or through a representative, and on a multi-well operator that is routinely one company for crude and a different one for gas. And §144 reaches the proceeds inuring to the working interest, not amounts payable under valid bona fide reservations of oil or gas payments or overriding royalty interests executed in good faith, so the number you can suspend is smaller than the gross check. Send it registered or certified and keep the return receipt, because §144.1 conditions the lien’s effect against that purchaser on delivery of the copy by exactly those means.

3. Whether You Outrank the Operator’s Bank Depends on the Unit

Section 144 carries its own priority sentence and it is narrower than the folklore around it. The lien is preferred to all other liens or encumbrances that attach to the leasehold, the wells, the material and machinery furnished and the fixtures and appliances on it subsequent to the commencement of, or the furnishing or putting up of, that machinery or those supplies. Compliance with the article then constitutes constructive notice of the claim to all purchasers and encumbrancers subsequent to the date the first item of material was furnished or the first labor performed. Read as written, that is a relation-back rule rather than a superpriority, and a mortgage recorded before your crew arrived does not become junior to you because you later did the work that kept the well alive.

The authority that says so out loud is a case where a drilling contractor lost seven figures on exactly this point. GasRock Capital, L.L.C. v. EnDevCo Eureka, L.L.C., 2013 OK CIV APP 98, 313 P.3d 1028, recounts an earlier ruling in which the United States District Court for the Western District of Oklahoma granted GasRock summary judgment against KAL Drilling Company. That court held that because the mortgage lien was recorded before KAL commenced its services, the mortgage was prior in time and hence superior to KAL’s §144 materialmen’s liens absent some legal basis for a conclusion to the contrary, and the Oklahoma court gave the federal order preclusive effect. KAL was owed over two million dollars for drilling services and had filed a lien statement, and it still finished behind the lender.

In the very same appeal a different contractor on the very same well came first, and the difference was the unit. Pan American Drilling Services beat that identical prior-recorded mortgage because the well sat inside the West Short Junction Unit, and 52 O.S. §287.8 gives a unit formed under the Unitization Act a first and prior lien on the leasehold estate and other oil and gas rights in each separately owned tract to secure unit expense. The Court of Civil Appeals had already held in TCINA, Inc. v. NOCO Investment Co., 2004 OK CIV APP 62, 95 P.3d 193, that the legislature expressly and unconditionally declared the §287.8 lien to be a first and prior lien, and that a land-record filing reflecting approval of the unit is itself sufficient perfection. The notice of Commission approval in that county had been sitting in the land records since January 1962, which is why a 2006 mortgage lost to it.

On the production proceeds the ranking turns your way, and this is the least understood fact in the whole area. In White Star the Oklahoma Supreme Court answered a certified question by holding that the Oil and Gas Owners’ Lien Act does not give operators and non-operating working interest owners a lien in proceeds superior to a §144 claimant. The reasoning is that a vendor holding a §144 lien on proceeds is itself an interest owner within 52 O.S. §549.2, in parity with them and entitled to the same super-priority. Section 549.7 provides that except for a permitted lien an oil and gas lien takes priority over any other lien, whether arising by contract, law, equity or otherwise, or any security interest, and §549.4 makes that lien perfected automatically without any financing statement. The court limited its answer to operators and non-operating working interest owners and expressly did not reach royalty owners.

4. Money in the Operator’s Account Is Already Held for You

Title 42, Section 144.2 is the provision an operator’s controller hopes you have not read. Subsection A says the amount payable under any oil and gas well drilling contract, reworking contract, operating agreement, or monies payable as a condition of participation in the drilling of a well under a Corporation Commission pooling order shall, upon receipt by the operator, contractor or subcontractor, be held by that operator as trust funds. What the trust secures is payment of all lienable claims due and owing by reason of that contract, agreement or pooling order. Subsection B forbids applying any portion to any other purpose until all lienable claims due or to become due have been paid, and subsection C makes the trust and the lien cumulative, so filing one does not release the other.

The scope of that trust went up to the Oklahoma Supreme Court and the operator lost. White Star argued the trust captured only joint interest billing payments, the reimbursements non-operating working interest owners send the operator for their proportionate share of costs, and the court reformulated the question and answered it in the negative, finding that nothing in the text or history of §144.2 limits the types of revenue that must be held in trust for lienable claims. The mandate the court read out of the section is a plain one, that any amount received, up to the amount of all lienable claims, is held in trust for payment of those claims until they are paid, and its manifest purpose is to secure the designated lienholders against the risk of insolvency or corrupt dealing of operators.

That changes the temperature of a collection call more than most vendors expect it to. When an operator explains that it will pay you once the joint interest billings come in, it has just described money Oklahoma already characterizes as trust funds for your claim, and on the court’s reading the same is true of production revenue it collects and of the participation money a force-pooled owner sends in. From the operator’s side, the answer that the cash is general working capital needed to make payroll stops being a business explanation and becomes a legal problem, and in an insolvency it turns into a fight over whether those funds were ever property of the estate in the first place.

Two honest limits belong here, because overselling this gets service companies hurt. Subsection D takes royalty payments out of the trust entirely and provides that the section does not affect or alter 52 O.S. §87.1. And §144.2 has no companion to 42 O.S. §153(B), which for building and remodeling contracts makes the managing officers of a corporation and the managers of a limited liability company liable for the proper application of trust funds and exposes them to punishment under 21 O.S. §1451. That personal and criminal overlay lives in the construction trust and does not appear in the oil and gas trust, so anyone telling you an operator’s principals face jail over your field tickets is reading the wrong section.

5. Your Funder Bought a Receivable the Operator Can Argue With

Start with how the money actually moves, because the account a funder purchased is not an ordinary trade receivable. Where a leasehold carries more than one working interest owner, operations run under a joint operating agreement or, where the owners have not agreed to pool, under a forced pooling order the Corporation Commission enters under 52 O.S. §87.1(e), and the operator drills and produces on behalf of itself and the other interest owners and then divides costs in proportion to each share. The Oklahoma Supreme Court described the mechanics plainly in White Star: the operator typically bears those costs first and then collects reimbursements, known as joint interest billing payments, from the other owners. Your invoice sits at the head of that chain and gets paid out of a collection process the operator runs and does not always win.

What a receivables buyer takes, it takes subject to that. Under U.C.C. §9-404 an assignee of an account acquires it subject to the terms of the agreement between the account debtor and the assignor, and to any defense or claim in recoupment arising from that transaction. It is subject as well to any other defense or claim of the account debtor that accrues before the account debtor receives notification of the assignment. Filing a financing statement against your accounts does not erase a backcharge for a redo, a fishing job, downtime on a unit that would not start, or a disputed day rate. What the funder purchased is your seat in whatever argument exists, and the price it paid assumed there was not one. Read your own agreement for a waiver of defenses clause, because U.C.C. §9-403(b) makes one enforceable by an assignee that took for value, in good faith and without notice.

The operator, meanwhile, is not a passive account debtor, and Oklahoma has armed it twice. Section 549.11 of Title 52 provides that the Oil and Gas Owners’ Lien Act does not impair an operator’s right to be paid, to set off, or to withhold funds from another interest owner as security for or in satisfaction of any debt or security interest. Section 87.1(e) then gives the operator of a force-pooled unit a lien on the mineral leasehold estate and rights of the other owners and upon their shares of unit production, to the extent development and operating costs are charged against those interests. That lien lasts until the operator is paid what the pooling order says it is owed. An operator caught between a non-paying working interest owner and you has statutory ways to squeeze upstream, and it will exhaust them before it writes your check.

The practical work is unglamorous and it decides the number. Keep field tickets signed by the company man, keep joint interest billing detail matched to your invoices well by well, and know before any negotiation which of your receivables are sitting behind an operator’s own collection fight rather than behind its unwillingness to pay. It also helps to know what Oklahoma thinks delay is worth: 52 O.S. §570.10(D)(1) prices proceeds from the sale of production that are not paid within the statutory windows at twelve percent per annum, compounded annually. Interest runs from the end of the month in which the production was sold until the day paid. That is the state’s own benchmark, and it is worth having in mind when an operator asks you to carry ninety days for nothing. If a funder has already written to your operators, our page on a UCC lien intercepting receivables covers what happens next.

6. The Workover Rig and the Vacuum Trucks Were Never in the Blanket

A blanket financing statement covering all assets is the instrument every funder uses, and in a service company it reaches far less iron than the language suggests, for two independent reasons. The first is purchase money. Under U.C.C. §9-324(a) a perfected purchase-money security interest in goods other than inventory or livestock has priority over a conflicting security interest in the same goods, so long as the purchase-money interest is perfected when the debtor receives possession of the collateral or within twenty days after. The lender that financed the rig, the pump truck or the tank battery and filed inside that window sits ahead of a blanket lender regardless of who reached the index first, which is why an advance funder’s recovery analysis on your equipment is usually wrong in its own favor.

The second reason is that Oklahoma takes titled vehicles out of the Article 9 filing system altogether. Section 1110 of Title 47, which the Legislature has amended in each of the last three sessions, provides that a security interest in a vehicle for which Service Oklahoma may properly issue a certificate of title is perfected only on delivery of a lien entry form to Service Oklahoma or to a licensed operator. That delivery has to carry the existing certificate of title or an application for one and the manufacturer’s certificate of origin, showing the secured party’s name and address and the date of the security agreement, along with the required fee. The same section states that the filing and duration provisions of Title 12A, including 12A O.S. §1-9-311, are not applicable to those vehicles, except as to vehicles a dealer holds for sale or lease.

There is a relation-back window inside that, and a competing creditor lives in the gap. Deliver the lien entry form, the lien filing fee and the certificate of title or the application within forty-five days after the date of the lien entry form and perfection begins from the date the form was executed, while a late delivery means perfection begins only on delivery. Then read the exclusion, because it splits a service fleet down the middle: for purposes of §1110 the word vehicle does not include special mobilized machinery, machinery used in highway construction or road material construction, or rubber-tired road construction vehicles including rubber-tired cranes. Title 47, Section 1-165 defines special mobilized machinery as special purpose machines, self-propelled or drawn, that derive no revenue from transporting persons or property. Their highway use must be only incidental, their revenue producing service must be performed away from the traveled surface, and they must carry no load beyond their own weight.

Where a particular unit lands is a question for counsel holding the registration and the build sheet rather than something to guess at over the phone, but the shape of the answer is clear enough to act on. A vacuum truck that earns its money hauling produced water down a highway is doing precisely what that definition excludes and it is titled, so a UCC-1 alone never touched it. A carrier-mounted workover rig that uses a road only to reach location may sit outside the word vehicle, in which case an ordinary Article 9 filing is what perfects against it and the blanket lien may in fact reach. Before conceding that a funder’s lien covers your yard, have somebody walk the fleet list against the titles and the lien entry forms, because in the files we work those two lists rarely match. Where equipment paper is itself part of the problem, see how to consolidate equipment loans and leases.

7. Plugging Liability Outlives Every Restructuring

Start with who owes the plugging, because service companies routinely assume the answer is somebody else. Under the Corporation Commission’s rule at OAC 165:10-11-3(b), promulgated under the authority of 17 O.S. §53(A), any working interest owner and operator of any oil, gas, disposal, injection or other service well is jointly and severally liable and responsible for plugging it. The same rule then defines other responsible persons to take in anyone exercising dominion and control over such a well without the authority or permission of the working interest owners or the operator, and those persons become jointly and severally liable alongside them. Read that with OAC 165:10-11-2(d)(2), which fixes plugging responsibility on a licensed plugging contractor that enters a well without having contracted with the operator or with a party holding authority to authorize the entry, and the warning to a service company is very concrete.

The money behind that duty sits in 52 O.S. §318.1, which was amended in 2025 and again on an emergency basis in May 2026 and is stepping up right now. Anyone who drills or operates a well for the exploration, development or production of oil or gas, or as an injection or disposal well, must furnish the Commission a written agreement to drill, operate and plug together with evidence of financial ability covering plugging, closure of surface impoundments and removal of trash and equipment. Category A surety, a financial statement proving net worth of not less than $50,000, stopped being available for new operators to select on November 1, 2025. Operators already holding valid Category A surety and in good standing keep it. Category B is cash or somebody’s written promise, tiered by well count, and an operator whose real liability is lower can certify down on a licensed well plugger’s affidavit.

Enforcement is the part that moves faster than any creditor, and it is why a vendor should watch an operator’s Form 1006B status the way it watches the aging report. Subsection F makes operating without the required evidence of financial ability unlawful and directs the Commission to shut in the violator’s wells without notice, hearing or order, with the wells staying shut in until Category B surety is obtained and verified. OAC 165:10-1-10(g) then bars any taker, transporter or purchaser from taking, transporting or purchasing oil or gas from those wells after receiving a copy of the shut-in order. Subsection E gives ten days from notification of a plugging failure before forfeiture runs, and subsection G requires a transferee of a well to furnish its own evidence of financial ability before the transfer, which closes the escape route a distressed operator reaches for first.

Hold those numbers against a real inventory and the lesson lands on you rather than on the operator. A statewide Category B ceiling of $150,000 regardless of well count means a vendor chasing an insolvent operator is not chasing a bonded obligation with a surety standing behind it, which is exactly why the §144 lien and the §144.2 trust are the assets worth protecting while that operator is still producing. One further pressure pushes operator cash toward plugging and away from your invoice. Section 53(B) of Title 17, added in 2025, requires operators of gas wells idle twenty years or more to cut idle counts twenty-five percent by July 1, 2028 and fifty percent by July 1, 2031. That section expressly declines to reset the clock on a sale, lease or transfer.

Where Produced Water Puts You Under the Commission

A water hauling or disposal business tends to assume its regulator is whoever inspects the trucks, and in Oklahoma that is a fraction of the picture. Section 139 of Title 52 vests the Corporation Commission with exclusive jurisdiction, power and authority, and imposes on it the duty, to make and enforce rules governing the handling, storage and disposition of saltwater, mineral brines, waste oil and other deleterious substances produced from or used in connection with the drilling, development, producing and operating of oil and gas wells. The stated purpose is preventing pollution of the surface and subsurface waters of the state. Subsection B carries that exclusive jurisdiction into underground injection control under the federal Safe Drinking Water Act and 40 C.F.R. parts 144 through 148, expressly including Class II injection wells, and subsection B(2) extends it to construction, operation, maintenance, site remediation, closure and abandonment.

Three permits and bonds attach to particular activities rather than to the industry generally, and a company usually discovers them the year it gets fined. Hauling more than twenty gallons of a deleterious substance requires a Deleterious Substance Transport Permit under OAC 165:30-3-13, issued by the Commission’s Transportation Division rather than by the Conservation Division. A permit holder must also keep valid liability insurance on file under OAC 165:30-3-11 or face revocation. Contracting to land apply fluids triggers OAC 165:10-7-10, which requires a $50,000 performance bond or an approved alternative and says in terms that financial statements are not an acceptable form of surety. And contracting to pull casing or plug wells requires a license under OAC 165:10-11-1, applied for on Form 1055, with a fine up to $2,500 and shutdown pending compliance for operating without one.

Owning the disposal well rather than trucking to somebody else’s puts you on a heavier schedule than an operator. OAC 165:10-5-5(f) requires the operator of a commercial disposal well facility to file an agreement to properly plug the well and reclaim the site on termination of operations. That agreement has to be backed by $25,000 of surety per facility, or by an amount set on a Form 1006D affidavit of plugging costs, capped at $250,000, in the form of a corporate surety bond, certificate of deposit, irrevocable letter of credit or another approved instrument. That $250,000 ceiling sits above the $150,000 statewide ceiling a producing operator faces under 52 O.S. §318.1, and it stacks on top of the operator surety rather than replacing it.

The conduct rule underneath all of it names service companies directly, which surprises people. OAC 165:10-7-5(a) requires that all operators, contractors, drillers, service companies, pit operators, transporters and pipeline companies conduct operations in a manner that will not cause pollution. The reporting duty then gives you twenty-four hours from discovery to notify the district office of any unpermitted discharge of ten barrels or more outside sufficiently impervious containment, or of any quantity reaching waters of the state, with a fine up to $500 per incident. Behind that sits 52 O.S. §296, on the books since early statehood, which still says flatly that salt water shall not be allowed to flow over the surface of the land.

The Claims That Compete With Every Creditor You Have

Anyone restructuring in this industry eventually asks whether the state can jump the line, and in Oklahoma the answer is unusually clean. We searched the whole Environmental Quality Code at Title 27A for a remediation or cleanup lien of the kind several states have written into their environmental statutes, and there is not one. The word lien appears in that title only inside an attorney-client privilege phrase and inside the Brownfields Act definition of a participant lender holding a bona fide security interest. There is no DEQ superlien in Oklahoma, and any page telling you otherwise has not read the title.

What does exist runs through the Corporation Commission and through fines rather than through cleanup costs. Under 52 O.S. §102, a fine or penalty assessed under the conservation statutes is enforceable in the same manner as a foreign judgment and constitutes a lien upon all the property of the offender within the state except the homestead, once a certified copy of the order is filed under 12 O.S. §706. Contempt fines under that scheme run up to $5,000 per day, with each day treated as a separate and additional contempt. Title 52, Section 610 does the same thing under the Energy Resources Conservation Act at up to $50,000 per day. Those are liens on everything you own, and they are dated from the filing rather than from the conduct.

There is also a state lien aimed squarely at oilfield iron, and its priority rule is the one worth memorizing. Under 17 O.S. §53.3(A), the State of Oklahoma has a lien on abandoned oil and gas well-site equipment on a lease site, including production and storage structures and their contents, in an amount equal to the cost of plugging all wells associated with that lease and restoring the site. It is perfected by a notice filed with the county clerk and recorded in the tract index and the mechanic’s lien journal. Abandonment is presumed after a year of no production, injection, disposal or testing where the last operator of record either has no valid §318.1 surety and cannot be located, or carries plugging liability exceeding its posted surety.

Then read subsection D, because it is the reason an equipment lender sleeps at night: the lien provided for in that section is subject to all prior perfected liens. The state does not leapfrog a purchase-money lender on a workover rig or a bank with an earlier filing, and subsection E makes the lien assignable by the Commission, which means it can end up in private hands. Separately, 52 O.S. §314 gives a party with no obligation to plug who nonetheless plugs, replugs or repairs a well a cause of action against those who were obligated, plus a lien on their oil and gas rights in the land and the equipment on it, which is a live claim if your crews cleaned up after somebody else.

Why a Rig Count Business Is Structurally Wrong for a Fixed Daily Debit

Every merchant cash advance is underwritten off trailing bank deposits and repaid through a fixed daily or weekly remittance, which means the product carries one embedded assumption: that next quarter’s deposits will look roughly like last quarter’s. That assumption behaves acceptably for a restaurant and badly for a company whose revenue is a function of how many rigs are turning and how many workovers survived somebody else’s capital budget review. Nothing about that revenue line comes down in a straight path. An operator defers a program and the work for that operator goes to zero rather than to eighty percent of normal, so deposits drop in steps and stay there until the program comes back.

Work the arithmetic and the mismatch stops being abstract. Take a company averaging $520,000 a month in deposits across a good six months that takes a $300,000 advance with a $420,000 purchased amount, remitting roughly $1,750 every business day over about a year. At $520,000 of deposits that remittance is close to eight percent of gross, which a well run service company absorbs. Let two operators push their workover programs to the following year and put deposits at $260,000 for a month, and the same unchanged $1,750 a day is running near sixteen percent of gross out of a business whose crew payroll, fuel, insurance and yard rent did not fall by half. These figures are illustrative and are not drawn from any published market data.

The funder is not confused about this, which is the part worth understanding before you call one. A receivables desk prices a portfolio rather than your cycle, and it can carry a known default rate inside its factor rate as long as the performing files pay on schedule, so volatility that is existential to you is a modeled cost to it. That is also why the reconciliation clause, where your agreement has one, is the single most important paragraph in the document and the one most owners have never read. It is the only place the contract acknowledges that revenue moves, and it usually conditions any adjustment on documentation delivered inside a narrow window.

The wrong response to a step down in deposits is the common one, which is a fifth position taken to bridge the gap until the program comes back, because that adds a remittance to a revenue line that has not recovered yet. The right sequence starts with the lien and trust work above, because those convert receivables into leverage rather than hope. And take advice before you change anything about how the debits are being paid, since revoking an authorization or moving the operating account is a legal act with consequences written into your agreement, and it commonly triggers default and acceleration language that is worse than the debit was.

Who Should You Call? Our Top-Rated Business Debt Firms

One firm on this list works the entire lifecycle of a business debt file, from stopping the daily debits through attorney-led negotiation, UCC lien removal, and a signed release. The other two cover broader debt categories that often sit alongside the advances. Choose accordingly.