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Which Professional Do You Actually Need for Your Mineral Rights?

Posted on by Leonardo

Mineral owners encounter a wide range of professionals: landmen, oil and gas attorneys, CPAs, Certified Mineral Managers, petroleum engineers, and mineral appraisers. The questions that keep surfacing — from an owner with 0.00145 net acres wondering whether an issue is worth pursuing, to a trustee trying to establish a defensible price for a beneficiary transaction — often come down to the same confusion: which professional actually handles the problem in front of you?

This post maps each professional to their actual scope of work and tells you how to match the right one to your situation before you spend money. For the full breakdown organized by situation rather than by professional, read Attorney, CPA, Landman, or Mineral Manager: Who to Hire for What.

Start With the Problem: Title, Value, Tax, or Management

The single most useful question to ask before hiring anyone is which category your problem falls into: legal title, valuation, tax, or ongoing management. Most owners skip this step and end up paying attorney rates for work a CMM would handle at a fraction of the cost — or paying a CMM to research a title defect that requires a lawyer.

An oil and gas attorney handles legal title, lease and conveyance drafting, probate and heirship matters, and legal defects in the ownership chain. A mineral appraiser determines value using production history, decline-curve analysis, market data, and comparable transactions. These are distinct deliverables and distinct scopes of work. A valuation professional is not a legal authority. An attorney who discusses value is not providing a formal independent appraisal.

If the problem is legal ownership or title, start with an attorney or CPL depending on the issue. If the problem is value, find a professional experienced in mineral valuation. If it involves both, you need coordination — which is exactly what a mineral management team that includes CPAs, CPLs, and Certified Mineral Managers provides under one engagement.

The Six Professionals You Will Actually Encounter

Oil and gas attorney. Interprets title, drafts and negotiates legal documents, advises on probate and heirship, and fixes legal title defects. The only professional who can render a formal title opinion or represent you in court. For multi-state mineral interests, the attorney must be licensed in — or coordinate with counsel in — each mineral state. Not a valuation professional.

Landman or Certified Professional Landman. Researches courthouse records, prepares ownership and title-status reports, negotiates leases and rights-of-way, and handles title curative work. A CPL is not a lawyer and cannot render a title opinion — but a CPL builds the chain a lawyer opines on. Putting an attorney on courthouse research is the most expensive mistake mineral owners make on title work. Valor’s team of CPLs handles this work across 32 states.

CPA or oil and gas tax accountant. Handles depletion schedules, stepped-up basis at death, 1099 reconciliation, severance tax, and the tax treatment of royalty income. A good oil and gas CPA understands percentage depletion and intangible drilling costs. Does not handle title or valuation. Documenting stepped-up basis at date of death is one of the highest-value tax moves in mineral ownership and it has to happen while the documentation trail is fresh.

Certified Mineral Manager. Trained specifically in ongoing administration — revenue reconciliation, division order review, lease compliance, operator communications, and portfolio reporting. This is the role most owners do not know exists and the one they most often try to force an attorney or CPA to fill. Those professionals will do it — at the wrong rate and with the wrong expertise.

Mineral appraiser or valuation professional. Provides an independent opinion of value as of a specific date using production data, decline curves, reserve estimates, commodity price forecasts, and comparable transactions. Most important for estate tax purposes, date-of-death valuation on inherited minerals, and fiduciary transactions involving beneficiaries. A mineral appraiser is not a petroleum engineer and not an attorney.

Petroleum engineer. Models production decline, estimates recoverable reserves, and evaluates well performance. Retained when a formal reserve report is needed — for financing, acquisition due diligence, or a large estate requiring a production-based value opinion. Most individual mineral owners will not need one.

When Small Interests Do Not Justify Professional Fees

This is the question most owners with fractional inherited interests face but rarely ask directly: is this worth it?

The answer depends on the value of the interest, the nature of the issue, the cost of resolution, and whether the issue compounds over time. A legal title defect on a 0.00145 net acre interest generating $4 per month probably does not justify a full quiet title action. An ownership gap on a 40-acre tract in an active formation almost certainly does.

Do the math before you hire anyone. What is the likely value of the interest if the issue is resolved? What will resolution cost? Is there a limitations period running that makes delay expensive? Valor’s mineral management team can run that triage before any professional fees are committed. For owners with very small interests working through what to prioritize, read Just Inherited Mineral Rights? Here Is Where to Start.

State Matters: Texas, Oklahoma, and Multi-State Ownership

Which professional you need depends in part on where the minerals are located. Texas and Oklahoma have meaningfully different legal frameworks and the differences matter.

Texas. Uses the original land grant survey system. Affidavits of heirship are a common and effective title curative tool. Texas courts have consistently upheld post-production cost deductions when lease language is silent — cost-free language must be explicit to hold up. The Railroad Commission governs oil and gas regulation. For a plain-language guide to reading Texas legal descriptions and locating a tract, read How to Locate Your Mineral Tract on a Map.

Oklahoma. Uses the federal PLSS grid. Force pooling through the Oklahoma Corporation Commission establishes documented bonus and royalty terms that function as public comparables — useful for benchmarking any offer in that area. Oklahoma’s Production Revenue Standards Act creates specific statutory remedies for late payment that do not exist in Texas. For a plain-language explanation of how force pooling works in Oklahoma compared to Texas, read Forced Pooling in Oklahoma vs. Texas.

Multi-state interests. Minerals pass under the law of the state where they sit — not the decedent’s home state. Out-of-state ownership requires ancillary probate or another state-authorized transfer procedure in each mineral state. An attorney licensed in or coordinating with counsel in the mineral state is not optional. For the full breakdown of what multi-state inheritance requires, read Inherited Minerals in a State You Don’t Live In.

Trustees, Executors, and Fiduciary Situations

Trustees and executors have a specific professional need that individual owners usually do not: independent valuation when a transaction involves beneficiaries or a potential conflict of interest.

A trustee selling minerals to a related party, or distributing an interest in kind to one beneficiary rather than another, needs a defensible independent valuation — not an offer letter or an operator’s estimate. The mineral appraiser provides that number. The attorney ensures the transaction is legally proper. The CMM handles the operational transfer. These are three separate jobs and they should not be collapsed into one.

For context on how mineral interests fit inside a trust structure and what trustees need to know operationally, read Minerals in a Trust: What Bankers, Trustees, and Mineral Owners Need to Know.

The Coordinated Team: When One Professional Is Not Enough

Many mineral situations require professionals working in sequence. The most common pattern: a CPL runs the title chain, the attorney identifies the defect and drafts the curative instrument, the CPL records it, and the CMM picks up ongoing administration once ownership is clean.

For a multi-state estate: the estate attorney handles domiciliary probate and coordinates ancillary proceedings, the CPL confirms title in each mineral state, the CPA establishes stepped-up basis at death, and the CMM handles operator notifications and division order updates.

The mistake owners make is forcing a single professional into all of these roles. An attorney charging hourly rates to monitor royalty statements and chase operator correspondence is doing CMM work at attorney prices. The coordinated model — each professional doing the work they are trained for — is faster and less expensive than a single generalist handling everything.

Valor’s team operates as that coordinated structure. The $27 million recovered since 2018 came from putting the right professional on the right problem at the right time. If you are not sure which role applies to your current situation, Contact Valor for a free review before committing to any professional fees.

Contact Valor Today

Not sure which professional you need — or whether the issue is worth pursuing at all? Contact Valor today for a free, no-obligation review. Our mineral management team of CPAs, CPLs, and Certified Mineral Managers will identify what your situation actually requires, handle the work that falls within our scope, and coordinate with attorneys, appraisers, and tax advisers where the situation calls for it. We manage mineral rights across Oklahoma, Texas, and 30 other states for owners, trusts, banks, and institutions.

The information provided by Valor in this blog is for general informational purposes only and is not intended to provide specific recommendations or legal or tax-related advice. This blog should not be used as a substitute for competent legal advice from a licensed attorney in your state.

Cost-Free Royalty Clauses: Why You Still See Deductions on Your Check

Posted on by Leonardo

In the past 36 months, Valor has recovered more than $32 million for mineral owners — and a meaningful share of that came from a single misunderstood contractual mechanic: where the operator legally sets the point of sale for royalty calculation. If your lease has a cost-free, no-deductions, or no-expenses royalty clause and you are still seeing deductions on your check stub, you are not necessarily being cheated. In most cases you are being paid according to a lease definition you may not have negotiated tightly enough.

This post explains the sale-point relocation mechanism, why it produces legal deductions under an ostensibly cost-free clause, and what mineral owners in Texas, Oklahoma, and across the other states Valor works in should do about it. For the foundational explanation of what post-production deductions are and how at-the-wellhead versus gross proceeds language controls them, read Why Is My Royalty Check So Small? Post-Production Deductions, Explained first.

What a cost-free royalty clause actually protects

A cost-free royalty clause — sometimes titled “no deductions,” “no post-production costs,” or “gross proceeds” — says the operator cannot deduct costs from your royalty before it is calculated. On its face it sounds absolute. In practice it protects royalty only up to a specific point in the production stream. That point is called the point of sale, and it is defined either explicitly in the lease or implicitly by the operator’s marketing arrangement.

Here is the mechanic that trips up most mineral owners. Royalty is calculated as a percentage of the value of production at the point of sale. A cost-free clause says the operator absorbs the costs required to make the product marketable and get it to the sale point. It does not say the operator absorbs costs incurred after the sale point. Those downstream costs — gathering fees paid to a midstream pipeline, compression at a booster station, processing at a gas plant, transportation to a downstream index hub — are typically netted out of the sales price, which lowers the number your royalty percentage is applied against.

This is why two owners with identical “cost-free” language can receive materially different net royalties from the same well. The difference is not the clause. The difference is where the operator drew the sale-point line. Valor’s mineral management team sees this pattern across the 500,000 wells we monitor: identical-looking lease language, radically different net proceeds.

How operators legally relocate the sale point

Operators have three common ways to set the sale point at or near the wellhead — each defensible under most lease forms and applicable case law in producing states.

Wellhead sale to an affiliate marketer. The producer sells the raw stream to a marketing subsidiary at the wellhead for an index-minus price. The index-minus deduction reflects everything the affiliate will spend downstream. That deduction is baked into the sales price, not itemized on the check stub. Your royalty is calculated on the depressed wellhead price.

Sale at the tailgate of a gathering system. The gathering fee is treated as a pre-sale cost the operator absorbs, but processing, treating, and transportation are treated as post-sale. Whether these are pre-sale or post-sale is a factual determination courts have gone both ways on. Texas courts generally hold that post-production costs are deductible unless the lease expressly prohibits them. Oklahoma’s implied covenant to market has historically been interpreted more favorably toward owners, but the specific lease language still controls in both states.

Btu-adjusted sale after processing. The operator sells residue gas and NGLs separately after processing, then allocates costs back against each stream. The check stub shows deductions labeled PROC, T&F, or FUEL — and under many lease forms these are legally supportable even where the lease says “no deductions,” because the sale of the processed products is defined as a separate downstream sale.

None of this is fraud. It is contract mechanics playing out as the lease was drafted. Which is precisely why the fix is contractual, not adversarial.

Reading your check stub for sale-point clues

The line items on your check stub are the fingerprints of the operator’s sale-point definition. A few patterns to watch for:

GPT / GATH — gathering and transport. If your lease says cost-free and you still see this, the sale point sits downstream of the gathering system.

COMP — compression. Deductibility depends on whether it is required to make the gas marketable, which is typically pre-sale, or to reach a better market, which is typically post-sale.

DEHY / TREAT — dehydration and treating. Usually required to make gas marketable and often absorbed under a strong cost-free clause, but not always.

PROC / P&F — processing and fractionation. Under a wellhead-sale definition, generally deductible.

T&F / TRANS — transportation and fuel to the market hub. Almost universally treated as post-sale.

A useful diagnostic: total your monthly deductions and divide by gross value. If the ratio consistently exceeds 20% on gas royalty, the sale point is set well upstream of the market and the cost-free clause is doing far less work than the language implies. Two patterns Valor has seen recently: a 28% purchaser-paid deduction on a 25% no-expenses lease, and a 40%+ gathering charge on Oklahoma horizontal wells. Both are within ranges that warrant a lease-language review. For a full guide to reading every line on your check stub, read How to Read Your Royalty Check Stub Line by Line.

What language actually moves the sale point downstream

If you have leverage at lease negotiation or renewal, the clause language matters more than the clause title. “No deductions” alone is insufficient. Strong protective language does three things at once.

Define the point of sale explicitly. Not at the wellhead, but at the tailgate of the processing plant, at a named interstate pipeline delivery point, or at a specific published index hub such as Henry Hub or Waha. If the lease says royalty is calculated on proceeds at the index price, downstream costs cannot be netted out because the index price already reflects them. This is the single most important variable in the entire clause. For a full breakdown of cost-free royalty language and how to negotiate it before you sign, read How to Negotiate an Oil and Gas Lease.

Enumerate the specific costs the operator cannot deduct. A well-drafted clause lists gathering, compression, dehydration, treating, processing, fractionation, transportation, marketing, and fuel — by name. Enumeration prevents an operator from arguing a specific cost falls outside a general “no deductions” phrase.

Address affiliate sales directly. Require that any sale to an affiliate be at arm’s length or at the price the affiliate ultimately receives from an unaffiliated third party. This closes the wellhead-sale-to-marketing-subsidiary loophole.

For owners who cannot renegotiate an existing lease, the leverage points shift to lease expiration, Pugh clause enforcement, ratification requests on new units, and where the facts support it, challenges based on the operator’s duty to market. Those challenges require careful legal analysis and a clean production and revenue record, which is why the record-keeping matters as much as the clause itself.

Three questions to send the operator in writing

If you suspect sale-point relocation is producing improper deductions, send these three questions to owner relations by certified mail before escalating:

What is the defined point of sale under my lease, and where in the production stream does it sit? Request the operator’s written interpretation of the royalty clause and the marketing arrangement documentation.

What is included in each deduction line on my check stub, and is each cost incurred before or after the defined point of sale? Request a cost-by-cost breakdown with the contract or tariff that governs each charge.

For any sale to an affiliate, what price did the affiliate ultimately receive from an unaffiliated third party? This targets the wellhead-sale-to-marketing-subsidiary structure directly.

The responses — or the refusal to respond — will tell you whether a line-by-line reconciliation is warranted. Persistent refusal to provide cost documentation is itself a red flag and in most states the owner has a statutory right to request detailed accounting. Valor’s royalty management team handles these reconciliations as part of standard portfolio oversight.

Contact Valor Today

If your check stubs show deductions your lease appears to prohibit, the answer is rarely a phone call to the operator. It is a line-by-line reconciliation of lease language, sale-point mechanics, and reported proceeds. Contact Valor today for a free, no-obligation review — our royalty management team will pull your lease, map the sale point against your check stub deductions, and tell you whether the math lines up with what your lease actually requires. We handle royalty audits and lease-language reviews for owners across Oklahoma, Texas, and 30 other states.

The information provided by Valor in this blog is for general informational purposes only and is not intended to provide specific recommendations or legal or tax-related advice. This blog should not be used as a substitute for competent legal advice from a licensed attorney in your state.

Before You Throw That Letter Away: How to Verify Any Mineral Rights Notice

Posted on by Valor

A letter arrived about your mineral rights. The return address is a company you have never heard of. It references a well you cannot place. It is asking for your tax ID or your signature.

Before you throw it away — read this first.

Last week on one of the most active mineral rights forums online, an owner asked whether a suspense notice from Plains Marketing was a scam. The top reply said “100000000% SCAM, throw that in the trash.” That answer was completely wrong. A landman in the same thread corrected it: he had a client who received the exact same kind of letter with $800,000 sitting in suspense behind it.

That scenario plays out constantly. In the past 36 months, Valor has recovered more than $28 million for mineral owners — and a surprising share of that money started with a letter the owner nearly threw away. This post walks through why most of these letters are legitimate, gives you a four-step routine to verify any letter in about 30 minutes, and identifies the narrow set of red flags that actually indicate a real scam.

Why mineral rights letters look like scams even when they are not

Valor manages more than 500,000 wells across 32 states and 13 basins. Across that footprint, the same categories of mail show up in owners’ mailboxes every week — and they almost always look worse than they are.

Three types account for the majority of concern:

Suspense notices. An operator is holding your royalty payments because something in the title chain, address, tax ID, or division order cannot be reconciled. The letter is a request for information, not a threat. Until you respond, your money sits in an account earning you nothing. If you believe funds may already be sitting in suspense, here is how to find unclaimed mineral funds.

W-9 requests from operators you do not recognize. Wells change hands constantly. The operator who drilled your section in 2014 may have sold the wellbore to a successor in 2022, who sold it again in 2025. Each time the operating interest transfers, the new payor is legally required to collect a fresh W-9 before cutting you a check. The company name on the letter will almost never match the name you have been dealing with. That is normal, not suspicious. For a plain-language explanation of what happens to your royalty payments when an operator sells, read What Happens to Your Royalty Payments When Your Operator Sells.

Unclaimed property notices from state treasurers. Every state escheats unclaimed royalty proceeds after a statutory dormancy period — typically three to five years. Treasurers then send notices to the last known address. These letters can look like phishing because they arrive out of nowhere and reference money the owner did not know existed. They are real.

None of these are scams. They are the mechanical output of a system that moves ownership, payments, and tax reporting across dozens of counterparties. The instinct to shred them is exactly what costs owners money. For the broader context on how these workflows fit together, our mineral management overview lays out the moving parts.

How to verify any mineral rights letter in 30 minutes

This routine works for almost any letter you will receive. You do not need a lawyer for steps one through four — only for the rare cases that fail all four.

Step 1: Identify the sender against public records. If the letter is from an operator, look up the company name on the Texas Railroad Commission’s operator query for Texas wells or the Oklahoma Corporation Commission’s website for Oklahoma. Legitimate operators have a P5 number in Texas or an OCC operator ID in Oklahoma. If the entity shows up in the state’s regulatory system with an active status, that is a strong first signal. If you cannot find them at all, that is worth noting before you respond.

Step 2: Match the property described in the letter to your records. The letter should reference a specific lease name, well name, API number, or legal description — section, township, and range, or abstract and survey. Pull your last division order or a prior check detail statement. If the property matches something you already own, the letter is almost certainly connected to a real interest. If you have never confirmed what you own at the county level, Valor’s courthouse mineral research guide walks through how to do that by state.

Step 3: Call the sender using a number you found independently. Do not call the number printed on the letter. Look up the operator’s main line through the state regulator’s records or their corporate website. Ask for owner relations, reference the letter, and confirm it originated with them. If the number on the letter and the number you found independently do not match, call the one you found yourself.

Step 4: Cross-check state treasurer notices at the source. Every state runs a free unclaimed property search — Texas at ClaimItTexas.gov, Oklahoma at the state treasurer’s site. If the notice references funds held by the state, that same claim should be searchable on the official portal using your name. If it shows up there, the letter is real.

The actual red flags that indicate a real scam

Real scams targeting mineral owners exist, but they do not look like suspense notices or W-9 requests. They look like unsolicited purchase offers and pressure tactics. Watch for these specific patterns:

Pressure to sign within days. Legitimate operators, state treasurers, and title companies operate on months-long timelines. Anyone insisting you must sign within 48 or 72 hours is manufacturing urgency to short-circuit your verification.

Requests for money upfront. No legitimate suspense release, W-9 processing, or unclaimed property claim requires you to pay a fee or wire funds. State treasurers return unclaimed property for free. Operators do not charge you to receive your own royalties.

Offers to buy your minerals sight-unseen at a flat per-acre number. A legitimate offer will let you take weeks to evaluate. A predatory one arrives with a check already enclosed and a deed pre-drafted, betting on your confusion. Before responding to any purchase offer, read Got an Offer to Buy Your Mineral Rights? How to Tell If It’s Actually Fair.

Payment instructions that route around normal channels. If a purported operator asks you to update banking information via a link in an email or send tax documents to a personal Gmail address, stop.

Vague property descriptions. A legitimate letter names the lease, well, or legal description. A scam letter tends to reference “your mineral interests” generically because the sender does not actually know what you own.

The through-line is simple: legitimate mail asks you to provide information. Fraudulent mail asks you to surrender something — money, signatures, or account access — before you have had time to think.

What ignoring a real letter actually costs you

The cost of throwing away a legitimate letter is not zero, and it compounds quietly.

A suspense notice ignored for 36 months means royalties sitting in the operator’s account instead of yours, and eventually escheating to the state. A W-9 request ignored means the operator withholds 24% backup withholding on every check going forward — money you have to chase back through your tax return. An unclaimed property notice ignored means the funds get harder to claim as time passes, because the documentation trail supporting your ownership gets colder.

Our mineral management team spends a real share of its time reversing the consequences of letters owners wish they had opened sooner. It is almost always cheaper and faster to respond to a legitimate letter in the first 30 days than to unwind the fallout years later. Valor is SOC 1 Type II certified, which means our controls around client data and communications are independently audited every year — the standard you should expect from anyone you hand a sensitive letter to.

If you are not sure which type of letter you received — division order, lease offer, or purchase offer — read Division Order, Lease Offer, or Buyout? How to Read the Letter About Your Mineral Rights before you respond to anything.

Contact Valor Today

If a letter arrived and still feels wrong after you have walked the four-step routine — or if you would rather not walk it alone — Contact Valor today for a free, no-obligation review. Our mineral management team will verify the sender, match the property to your ownership records, and tell you exactly what the letter is and what to do next before you sign, send, or shred anything. We handle letter verification, suspense releases, and unclaimed mineral fund recovery for owners across Oklahoma, Texas, and 30 other states.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. This blog should not be used as a substitute for competent legal advice from a licensed professional attorney in your state.

How to Read Your Royalty Check Stub Line-by-Line

Posted on by Leonardo

In the past 36 months, Valor has recovered more than $32 million for mineral owners — almost all of it found by reading check stubs the way an auditor reads a tax return, line by line. Most owners glance at the net figure, confirm it cleared the bank, and file the stub away. That habit is expensive. The stub is the only document an operator gives you each month that ties production volumes, prices, taxes, and deductions back to your decimal interest, and every one of those fields is a place where money can quietly go missing. This post walks the stub from top to bottom so you know what each column should say, what it shouldn’t, and which lines deserve a second look before you cash the check.

Start at the Top: Property, Product, and Decimal Interest

Before any dollars appear, the stub identifies the property (lease name, well name, or property number), the product (oil, gas, NGLs, condensate, plant products), the production month, and your decimal interest. The decimal is the single most important number on the page — it determines every dollar that follows.

Pull your division order and confirm the decimal on the stub matches what you signed. A transposed digit (0.00125000 vs. 0.00012500) is a 10x error that compounds every month until you catch it. If you own across multiple wells in multiple states — Valor manages mineral interests across 32 states and 13 major basins — you should be reconciling decimals well by well, not in aggregate.

Also confirm the product type. Gas wells frequently produce condensate and plant products (ethane, propane, butane, natural gasoline) that show up on separate lines with separate prices and separate deduction structures. Missing lines are common when a new product stream comes online mid-year.

Gross Value: Volume, Price, and Decimal Interest

Gross value is the math the operator did before taking anything out. Three inputs drive it: the volume attributed to your interest (BBL for oil, MCF or MMBtu for gas), the price per unit, and your decimal interest. The stub should show all three.

Check the price against the posted price for that month and that basin. Permian WTI, Midland-Cushing differential, and Waha gas pricing all move independently, and a stub that shows a price meaningfully below the regional benchmark is worth a question. For gas, watch whether the price is quoted per MCF or per MMBtu — the BTU adjustment can swing your gross by 5-15% depending on the gas stream.

Volumes should reconcile to what the operator reports to the state regulator. Texas Railroad Commission production reports and Oklahoma Corporation Commission filings are public. If your stub shows materially less volume than the regulator filings for the same month, the difference needs an explanation. Our mineral management team runs this reconciliation as standard practice across every property under management.

Severance Tax: Predictable, but Worth Verifying

Severance tax is the state’s cut for the privilege of producing minerals. In Texas, the base production tax rate is 4.6% of market value for crude oil and condensate, and 7.5% of market value for natural gas. Certain fees, exemptions, credits, or reduced tax rates may also apply depending on the well, product type, and qualification status, so the severance tax line is worth spot-checking instead of assuming it is always standard.

In Oklahoma, gross production tax rules can vary depending on the well type, production period, and applicable incentives or exemptions. While oil and gas are commonly subject to a 7% gross production tax rate, owners should verify the rate shown on their stub against current state rules or ask the operator for support.

Two things to watch. First, severance should be calculated on gross value before deductions, not on net. Operators occasionally calculate it on a reduced base, which understates the tax line and can mask other accounting choices upstream. Second, some wells qualify for severance tax reductions or exemptions (high-cost gas, enhanced recovery, marginal wells). If your stub shows a reduced severance rate, you want to know why — because when the exemption expires, your net will drop without anything else changing.

Post-Production Deductions: Where Most Underpayments Live

This is the section that pays for our audit work. Post-production deductions cover the cost of moving and conditioning the product between the wellhead and the point of sale: gathering, compression, dehydration, treating, processing, and transportation. They appear as separate line items or rolled into a single “deducts” figure, and whether they’re allowed at all depends on your lease language.

Three questions to ask on every stub:

  • Does your lease permit post-production deductions, or does it have a “no deductions” or “market enhancement” clause that should zero this column out?
  • Are the deductions proportional to gross — or has the deduction percentage crept up over time without a corresponding change in the gathering or processing arrangement?
  • Are you being charged for services on products that aren’t yours? NGL processing costs sometimes get allocated against residue gas owners who never received the NGL revenue.

A 15% deduction load on a $5,000 monthly check is $750 a month — $9,000 a year per well. Multiplied across a portfolio, this is the line item that has driven the bulk of the $32 million Valor has recovered. Our team — CPAs, CPLs, and CMMs — reviews lease language against actual deduction practice as part of standard mineral management. You can meet the people who do that work on our team page.

Net Payment, Prior-Period Adjustments, and Suspense

Net payment is what remains after your share of gross value is reduced by severance taxes, post-production deductions, and any adjustments. On many royalty statements, the decimal interest has already been applied by the time you see the gross value column, so avoid applying it twice when checking the math. Once you calculate the expected net amount, compare it to the deposit in your account. If the numbers do not match, the difference usually appears in one of two places: prior-period adjustments or suspense.

Prior-period adjustments (sometimes labeled PPA, “corrections,” or “prior month”) are operator-initiated changes to past production months. They can be legitimate — a delayed meter reading, a price true-up, a tax refund — or they can be a quiet way to reverse income recognized in a prior year. Either way, every PPA line should be explainable. Ask for the underlying detail if it isn’t.

Suspense is money the operator is holding rather than paying you. Common reasons include unsigned division orders, title questions, address changes, or amounts below the operator’s minimum check threshold (often $25 or $100). Suspended funds belong to you and should be released as soon as the underlying issue is resolved. If you have a stub showing suspense for more than two consecutive months without movement, that’s a phone call.

If reviewing every stub, every month, across every well isn’t realistic for your portfolio, that’s the work we do. Valor manages more than 500,000 wells across 32 states under a SOC 1 Type II–certified process, and we’ve put $32 million back into mineral owners’ pockets doing exactly this kind of line-by-line review. See how it works on our Mineral Management overview.

Contact Valor Today

Need help understanding what your royalty check stub is really telling you? Contact us today to see how our mineral management solutions can help you organize records, verify payments, monitor deductions, and manage mineral assets with greater clarity and control.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. The blog/website should not be used as a substitute for competent legal advice from a licensed professional attorney in your state.

Mineral Interests in a Trust: What Bankers, Trustees, and Mineral Owners Need to Know

Posted on by Leonardo

A bank trust officer in Dallas inherits a portfolio with 1,200 mineral interests scattered across four states. The previous administrator left a binder of lease copies and a spreadsheet last updated in 2019. Royalty checks arrive from 40 different operators, deductions look inconsistent, and the beneficiaries want to know what the assets are worth. This is the position most fiduciaries find themselves in when mineral rights land inside a trust — and it is exactly the work Valor has built around. In the last 36 months, our team has recovered more than $32 million for mineral owners by auditing payments, curing title, and reconciling revenue that operators got wrong. This post walks through what bankers, corporate trustees, and individual trustees need to know when minerals sit on the trust balance sheet, and where the real exposure lives.

Why Mineral Interests Are Different From Every Other Trust Asset

A trustee can value a stock portfolio in seconds and a piece of real estate in a week. A mineral portfolio resists both. Production declines on a curve, prices move daily, operators come and go through bankruptcy and acquisition, and the underlying ownership often traces back to deeds written before air conditioning existed. Valuation, income forecasting, and even basic asset identification all require specialized work.

Layer on the fiduciary duty. A trustee is legally required to manage assets prudently for the benefit of named parties. When the asset is a 1/64th non-participating royalty in a Reeves County section, prudence means knowing whether the operator is paying correctly, whether the lease is still in primary or held by production, and whether the division order matches the deed. Many trust departments are built to manage securities, real estate, and estate administration — not multi-state mineral portfolios with operator payments, division orders, lease terms, suspense issues, and title history. Individual trustees face the same challenge with even fewer resources.

The result is predictable: minerals sit in trust portfolios under-administered for years, and the gap between what beneficiaries are owed and what they actually receive grows quietly. Valor’s mineral management practice exists to close that gap.

The Three Places Trustees Lose Money on Mineral Interests

Across the 500,000 wells Valor manages and the $650 million in annual client revenue we support, the patterns are consistent. Trust-held mineral interests can lose value in three predictable ways.

Underpayment and missed payments. Operators make mistakes. Decimal interests get keyed wrong, suspense accounts hold funds that never get released, and post-production deductions get applied where the lease does not permit them. Without a systematic audit, no one catches it. The $32 million Valor has recovered for clients in 36 months is, in large part, money that was already owed and simply never reached the owner.

Title and ownership decay. Trusts hold assets across generations. Names change, beneficiaries die, sub-trusts get carved out, and deeds get recorded in counties no one remembers. When an operator can’t confirm clean title, they suspend the payment. Curing that title is detailed work that requires real land expertise.

Lease management failures. Top leases get signed without coordination with the trustee. Pugh clauses expire unnoticed. Bonus payments arrive that should have been negotiated higher. Each of these is a discrete event that, taken individually, looks small. Across a 1,000-interest portfolio over ten years, it is not small.

Why SOC Certification Matters for Bank Trustees

For a corporate trustee or bank trust department, the question is not just whether someone can manage minerals — it is whether the firm doing the work has documented processes and controls. Valor is SOC-certified, which gives trustees added confidence in the systems, reporting, and oversight behind the work.

That matters when the trustee’s own auditors come knocking, when a regulator asks how revenue figures on a trust statement were produced, or when a beneficiary challenges a distribution. Trustees need more than mineral expertise. They need a partner with a defensible process.

Valor’s team — built around CPAs, CPLs, and Certified Mineral Managers — operates within that controls-focused environment. 

What Outsourced Mineral Administration Looks Like in Practice

For a bank trust department or a corporate trustee, the practical model is straightforward. Valor takes the mineral portfolio onto our platform, builds the ownership and lease records out, audits the recent revenue history, and then runs the asset on an ongoing basis — receiving checks, reconciling to expected production, paying property taxes, handling division orders and lease offers, and reporting back to the trustee on a schedule the beneficiaries can rely on.

Coverage is broad. Valor operates across 32 states and 13 major basins including the Permian, Anadarko, Eagle Ford, Bakken, Marcellus, DJ, and Powder River. For a trust with assets spread across Texas, Oklahoma, New Mexico, North Dakota, and Pennsylvania, that footprint matters — most boutique firms only cover one or two states.

For trustees and beneficiaries who want to see how the work is framed and the recovery results delivered, the two-minute Valor story video is the quickest orientation.

Questions Every Trustee Should Be Able to Answer

Whether you handle minerals in-house or with a partner, a fiduciary should be able to answer the following at any time:

  • How many mineral interests does the trust own, and where are they located by state and county?
  • What is the trailing twelve-month revenue, and how does it compare to prior periods?
  • Which interests are leased, which are open, and which leases expire in the next 24 months?
  • Are there any interests currently in suspense, and what is required to release them?
  • When was the last full payment audit performed?

If those answers require a multi-week project, the administration is under-resourced. That is a fiduciary risk, not just an operational inconvenience.

If you are a banker, corporate trustee, or individual trustee carrying mineral interests on a trust balance sheet and you want a clear picture of what is owned, what is owed, and where the exposure lives, contact Valor for a portfolio review. Valor can help trustees identify what is owned, what is producing, what may be underpaid, and where administrative exposure exists — before small issues become beneficiary questions.

Contact Valor Today

Contact us today if you need help see how our mineral management solutions can help trustees organize, optimize, and monitor mineral assets with greater clarity and control.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. The blog/website should not be used as a substitute for competent legal advice from a licensed professional attorney in your state.

Valor | Energy Connection – Apr. 20, 2026

Posted on by Valor

April 20, 2026 Edition

At Valor, our goal is to keep you informed of the latest news and updates from the oil and gas industry. We are committed to sharing the insights and knowledge that our team gathers to help you stay ahead in this dynamic sector. From mergers and acquisitions to regulatory changes and technological advancements, we cover all the key developments that impact the industry. Stay tuned for weekly updates to keep you well-informed.

  • U.S. oil, gas drilling activity slows
  • Summary: The U.S. total rig count fell to 543 this week, with oil rigs slipping by one to 410 and gas rigs decreasing by two to 125, according to Baker Hughes. While weekly crude production remained steady at 13.596 million bpd, the Frac Spread Count grew by five crews following a previous seven-crew gain. Oil prices plummeted on news that Iran reopened the Strait of Hormuz, with Brent dropping 10.46% to $88.99 and WTI falling to $83.24 as the market reacted to the potential easing of shipping logistics.
  • Read more

    Big oil plows billions into far-flung drilling sites to escape Iran turmoil
  • Summary: ExxonMobil and Chevron are redirecting billions toward global exploration in Nigeria, Venezuela, and Greece to mitigate revenue losses and supply risks. Wood Mackenzie estimates major firms could create $120 billion in value from these ventures, following Exxon’s 6% production hit and $5 billion revenue loss due to damaged facilities in Qatar. While U.S. oil futures trade near $88, companies are utilizing windfall cash to secure reserves for the 2030s.
  • Read more
  • Permian constraints keep Waha gas prices negative for record stretch as U.S. markets weaken
  • Summary: Permian pipeline constraints have kept Waha Hub natural gas prices negative for a record 47 consecutive days due to trapped associated gas and limited takeaway capacity. On April 14, mild weather and strong renewable output pushed spot power and gas prices below zero in Texas and California, including the SP-15 hub. While hydropower generation remains above normal at The Dalles Dam, high production and infrastructure bottlenecks continue to pressure domestic pricing despite global volatility.
  • Read more
  • Middle East oil output may take two years to recover
  • Summary: ICE Brent fell below $90 per barrel as markets assess near-term supply expectations and potential changes in global shipping flows. OPEC crude output declined significantly last month, while China’s domestic production reached a record level in March. Amid these shifts, ExxonMobil adjusted initial LNG cargo activity at Golden Pass, as analysts warn regional supply recovery could take an extended period.
  • Read more

    Trading desks boom while big oil output stalls
  • Summary: European supermajors Shell, BP, and TotalEnergies expect exceptional Q1 2026 earnings driven by oil and gas trading profits amid extreme volatility where Brent for immediate delivery spiked to $150. While TotalEnergies saw 15% of its global production shut in due to Middle East conflict, a 10% increase in LNG production and new startups in Brazil and Libya helped offset these losses. Conversely, U.S. majors Exxon and Chevron face mixed results, with combined hedging and refining losses.
  • Read more

    Weather-driven demand supports natural gas market today
  • Summary: May Nymex natural gas rose for a fourth straight session, recovering from a low of $2.561 as above-average heat forecasts for April 22–26 boost cooling demand in the Southeast and Midwest. Despite this rally, a steep three-month downtrend persists, capped by record U.S. production exceeding 111 bcf/day and inventories sitting nearly 6% above the five-year average. While damage to Qatar’s Ras Laffan facility tightens global LNG supply, domestic oversupply remains a ceiling for near-term gains.
  • Read more

    Oil slides but the real test comes this weekend
  • Summary: ICE Brent fell below $90 per barrel as markets anticipate U.S.-Iran talks in Islamabad to end a 45-day blockade of the Strait of Hormuz. OPEC crude output plunged by a record 7.88 million bpd last month to 20.79 million bpd, while China’s domestic production hit an all-time high of 4.51 million bpd in March. Amid these shifts, ExxonMobil withdrew its first two Golden Pass LNG cargoes despite the plant taking in 290 million cf/day, as the IEA warns regional recovery could take at least two years.
  • Read more

Contact Valor Today

Contact us today if you need help outsourcing your oil and gas operations.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. The blog/website should not be used as a substitute for competent legal advice from a licensed professional attorney in your state.

Valor | Energy Connection – Nov. 10, 2025

Posted on by Valor

November 10, 2025 Edition

At Valor, our goal is to keep you informed of the latest news and updates from the oil and gas industry. We are committed to sharing the insights and knowledge that our team gathers to help you stay ahead in this dynamic sector. From mergers and acquisitions to regulatory changes and technological advancements, we cover all the key developments that impact the industry. Stay tuned for weekly updates to keep you well-informed.

  • U.S. drillers boost oil and gas rigs again, signaling shift in energy
  • Summary: The U.S. oil and gas rig count rose by two to 548 for the week ending November 7, marking the third increase in four weeks, though the total remains 6% (or 37 rigs) below last year. Baker Hughes reported that oil rigs held steady at 414, but gas rigs rose by three to 128, the highest since August 2023, while the Texas rig count fell to a new low of 234. Despite a planned 4% capex cut in 2025, the EIA projects crude output will rise to 13.5 million bpd, and a 56% gas price hike will boost gas output to 107.1 bcfd.
  • Read more

  1. Horizontal well declines require more drilling to sustain production
  2. Summary: U.S. oil and gas production relies on new drilling, as horizontal wells (94% of oil, 92% of gas) decline rapidly. From Dec 2023 to Dec 2024, L48 crude oil production from legacy wells fell by 4.3 million b/d, but 4.4 million b/d from over 15,000 new wells replaced this loss, increasing total output to 11.2 million b/d. During the same period, natural gas production saw legacy declines of 27.0 Bcf/d, but new wells added 28.0 Bcf/d, pushing the total to 116.5 Bcf/d in Dec 2024.
  3. Read more

  1. Crude oil weekly outlook: Market sentiment pressures prices
  2. Summary: Risk-off sentiment, driven primarily by the prolonged U.S. government shutdown that began in early October 2025, continues to pressure U.S. oil prices, which are holding near the mid-zone of a long-term downward channel, slightly above the $59 mark. The market is also weighed down by AI-related layoffs and stretched sentiment, while Chinese CPI rose to +0.2%, and U.S. stock indices are testing critical support. A confirmed technical break below the yearly low of $55 could push WTI toward $49, while a breakout above short-term resistances at $63 and $66.80 is required to signal a structural recovery toward $70.
  3. Read more

  • Gas futures capped by warm weather and production surge
  • Summary: December natural gas futures fell 0.96% to settle at $4.313, pressured by forecasts for unseasonably warm U.S. weather, which is expected to dent heating demand. Bearish sentiment was reinforced by strong supply, as U.S. dry gas production hit 110.0 bcf/day (up 8.1% year-over-year) and the active rig count rose to a 2.25-year high. While the EIA’s +33 bcf storage injection was below the 5-year average, total U.S. gas inventories remain ample at 4.3% above the seasonal norm, capping any bullish momentum.
  • Read more

  • SLB completes $8.2 billion ChampionX deal, expands in Permian
  • Summary: SLB has completed its $8.2 billion acquisition of ChampionX, a deal announced last spring that significantly expands its offerings in the resilient Permian Basin. The combined entity will offer integrated services from well construction and artificial lift to advanced chemicals and digital monitoring. SLB is now focused on deploying new advanced technology to help operators drill faster and longer laterals, while also investing heavily in digital solutions for efficiency and safety, as well as green chemistry for the beneficial reuse of produced water.
  • Read more

  1. The $30 break-even project driving Exxon’s success
  2. Summary: ExxonMobil’s Q3 2025 earnings were supported by strong production (4.8 million boe/d, up 4% YoY) despite Brent prices falling 13% YoY. The performance was driven by the Permian and Guyana’s Stabroek Block, where production exceeded 850,000 b/d from an asset holding at least 11 billion barrels. This Guyana asset is highly profitable with a low $30/barrel breakeven price and a favorable 2% royalty rate, with future projects expected to boost total capacity to 1.5 million b/d by 2029.
  3. Read more

  1. Oil settles lower on strong dollar and oversupply fears
  2. Summary: Oil prices settled lower on Tuesday, with Brent crude down 0.7% to $64.44 a barrel and WTI down 0.8% to $60.56. Prices were pressured by a stronger U.S. dollar (a four-month high against the euro), weak Japanese manufacturing data, and fears that the 35-day U.S. government shutdown could hurt fuel demand. This bearish sentiment was amplified by supply glut concerns after OPEC+ paused its output hikes for Q1 2026, while the price boost from recent U.S. sanctions on Russian oil firms also faded.
  3. Read more

Contact Valor Today

Contact us today if you need help outsourcing your oil and gas operations.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. The blog/website should not be used as a substitute for competent legal advice from a licensed

Valor | Energy Connection – Nov. 3, 2025

Posted on by Valor

November 3, 2025 Edition

At Valor, our goal is to keep you informed of the latest news and updates from the oil and gas industry. We are committed to sharing the insights and knowledge that our team gathers to help you stay ahead in this dynamic sector. From mergers and acquisitions to regulatory changes and technological advancements, we cover all the key developments that impact the industry. Stay tuned for weekly updates to keep you well-informed.

  • The oil glut will last into 2026. Here’s why it’s unclear how big it will be.
  • Summary: An oil glut, currently at 1.9 million b/d, is expected to last through 2026, but its size is now uncertain following new U.S. sanctions on Russian producers Rosneft and Lukoil. The IEA previously projected the surplus could reach 4 million b/d, a forecast that has kept Brent crude down 13% (to ~$64) and WTI down 14% (to ~$60) this year, below the $63 breakeven price for U.S. drillers. The sanctions’ impact is the key variable, with Goldman Sachs estimating a severe 1.5 million b/d supply cut could push prices toward $73 (WTI $63).
  • Read more

  1. Natural gas prices navigate volatility amid global shifts
  2. Summary: Natural gas markets remain volatile due to a tug-of-war between strong U.S. production and uncertain demand as the peak winter season begins, with prices consolidating since March 2023. The 2025–26 winter is expected to be colder, with heating degree days projected to rise 3% in the U.S. and Europe, and U.S. residential/commercial demand forecast to increase by 1.6 Bcf/day year-on-year. Global gas demand is projected to grow 1.7% in 2025, while China’s domestic production has risen 6%, reducing its recent LNG imports.
  3. Read more

  1. US rig count falls for the first time in three weeks, says Baker Hughes
  2. Summary: For the second straight week, the U.S. oil and gas rig count rose, climbing by two to 550 as of October 24, its highest level since June, though it remains down 6% year-over-year. This increase was driven entirely by oil rigs, which rose by two to a new total of 420, while gas rigs held steady at 121; the Texas rig count fell one to a low of 236. Despite a planned 3% capex cut for 2025, the EIA projects crude output will rise to 13.5 million bpd and a 56% gas price hike will boost gas output to 107.1 bcfd.
  3. Read more

  • Exxon and Chevron boost production despite weak oil prices
  • Summary: U.S. oil majors Exxon and Chevron increased Q3 production despite forecasts of a global supply glut and weak prices, with WTI hovering near $60/bbl. Exxon’s overall production rose to 4.8 million bbl/day, driven by a record 1.7 million boe/day in the Permian and 700,000 bbl/day in Guyana. Chevron’s output also hit a record 4.1 million bbl/day, up 21% Y/Y, as WTI closed the week at $60.98, Brent at $65.07, and the EIA forecasts Brent falling to $52/TYPE/bbl in 2026.
  • Read more

  • BP to sell $1.5 billion in US midstream asset stakes
  • Summary: BP has agreed to sell non-controlling stakes in its bpx energy midstream infrastructure to private investment firm Sixth Street for $1.5 billion, advancing its capital optimization strategy. The deal includes 49% of the US Permian assets (including pipelines and four processing facilities) and 75% of the Eagle Ford midstream system, with BP remaining the operator. This transaction, paid as $1 billion upfront and $500 million by year-end, helps BP recycle capital and moves it toward its $20 billion divestment target by 2027.
  • Read more

  1. Chevron’s Hess acquisition boosts third-quarter output
  2. Summary: Chevron reported strong Q3 results, with adjusted EPS of $1.85 (beating $1.68 expected) and record production of 4.1 million boepd, up from 3.4 million boepd a year earlier, following its $53-billion Hess acquisition. The production increase reflects the integration of Hess’s Guyana operations and higher domestic shale output, while operating cash flow (ex-working capital) climbed nearly 20% year-on-year to about $9.9 billion. Chevron management reaffirmed plans to cut $2-3 billion in costs through 2026 by streamlining operations and consolidating overlapping positions from the Hess acquisition.
  3. Read more

  1. SM Energy and Civitas Resources to combine in $12.8 billion deal
  2. Summary: SM Energy and Civitas Resources are merging in an all-stock deal valued at $12.8 billion (including debt), creating a top independent U.S. producer with 823,000 net acres in the Permian and DJ basins. Civitas shareholders will receive 1.45 SM Energy shares per share, valuing Civitas at $30.29 (a 5% premium), and will own 52% of the combined company, which retains the SM Energy name. Expected to close in Q1 2026, the firm had pro forma Q2 production of 526 MBoe/d, expects $1.4B in 2025 free cash flow, and $200M in annual savings.
  3. Read more

Contact Valor Today

Contact us today if you need help outsourcing your oil and gas operations.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. The blog/website should not be used as a substitute for competent legal advice from a licensed professional attorney in your state

Valor | Energy Connection – June 16, 2025

Posted on by Valor

June 16, 2025 Edition

At Valor, our goal is to keep you informed of the latest news and updates from the oil and gas industry. We are committed to sharing the insights and knowledge that our team gathers to help you stay ahead in this dynamic sector. From mergers and acquisitions to regulatory changes and technological advancements, we cover all the key developments that impact the industry. Stay tuned for weekly updates to keep you well-informed.

  • Oil prices fall more than $1 barrel on reports Iran seeks truce with Israel
  • Summary: Oil prices fell 1.3% as Israel-Iran strikes spared key infrastructure, despite initial surges and Friday’s 13% spike. Iran’s gas field saw partial shutdown but Strait of Hormuz flows remained uninterrupted. Iran rejected ceasefire talks amid attacks while OPEC+ holds spare capacity matching Iran’s output.
  • Read more

  1. Iran suspends partial output at major gas field after Israeli attack
  2. Summary: Iran partially suspended production at South Pars, the world’s largest gas field, after an Israeli strike caused a fire, halting 12M cm/day output (4% of Iran’s 275 bcm annual production). The attack marks Israel’s first strike on Iran’s energy sector, escalating tensions that pushed oil prices up 9% Friday. While Iran consumes all its gas domestically due to sanctions, neighboring Qatar exports 77M tonnes annually from the shared field with Exxon and Shell.
  3. Read more

  1. European gas prices rise with Middle East conflict intensifying
  2. Summary: European gas prices rose 2.4% to April highs after Friday’s 4.8% jump as Israel-Iran clashes entered day four, raising fears of Strait of Hormuz disruptions. The key waterway handles 20% of global LNG shipments, though current flows remain unaffected. With Europe in peak stockpiling season, any supply interruption could significantly tighten markets amid escalating Middle East tensions.
  3. Read more

  • Texas governor signs oil theft laws, funds $123M project
  • Summary: Texas Governor Abbott signed 5 bills combating oilfield theft (SB 494/1806, HB 48) and allocated $123M for Midland-Odessa’s Beacon project to boost healthcare and economic growth. The laws create a DPS oilfield theft unit and task force to address rising pipeline thefts in the Permian Basin, which fuels Texas’ economy. Key measures include tax code changes (SB 529) and enhanced law enforcement tools to protect energy infrastructure from organized crime.
  • Read more

  • Baker Hughes reports U.S. rig count down 4 to 559 rigs
  • Summary: U.S. rigs dropped 4 to 559 (oil -9 to 442, gas +5 to 114), marking a 35-rig annual decline. Canada added 2 rigs to 114 (gas +2 to 46), but remains 29 below 2024 levels. Offshore activity held at 13 rigs (-9 y/y). The report shows continued oil sector contraction with U.S. gas rigs up 16 annually while Canadian gas rigs fell 9. North American drilling activity remains depressed versus last year, with U.S. oil rigs down 50 and Canadian oil rigs down 20 year-over-year. The mixed results highlight shifting energy sector priorities amid changing market conditions.
  • Read more

  1. Abu Dhabi-based consortium launches $32b takeover tilt for Santos
  2. Summary: An Abu Dhabi-led consortium (ADNOC/XRG, ADQ, Carlyle) proposed a $32B takeover of Santos at A$8.89/share (28% premium), aiming to boost XRG’s LNG capacity to 20-25Mtpa by 2035. The deal would give ADNOC Asia-Pacific LNG assets (Santos produced 5Mtpa in 2024, could reach 8Mtpa) but faces FIRB scrutiny over energy security concerns. Regulatory hurdles may include domestic gas supply conditions, though counterbids are unlikely given ADNOC’s strategic fit and Santos’ capital needs.
  3. Read more

  1. RRC mapping automation portal now available online
  2. Summary: Texas’ Railroad Commission launched RRC MAP, an online portal requiring oil/gas operators to update real-time gas facility data for power generation supply chains during emergencies. The system shares data with Texas’ Utilities Commission to identify critical infrastructure under SB 3/HB 3648 laws, linking upstream production to power plants. Operators receiving RRC emails must submit requested data, with training materials and compliance procedures available on the RRC website.
  3. Read more

Contact Valor Today

Contact us today if you need help outsourcing your oil and gas operations.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. The blog/website should not be used as a substitute for competent legal advice from a licensed professional attorney in your state.

Valor | Energy Connection – Mar. 3, 2025

Posted on by Valor

March 3, 2025 Edition

At Valor, our goal is to keep you informed of the latest news and updates from the oil and gas industry. We are committed to sharing the insights and knowledge that our team gathers to help you stay ahead in this dynamic sector. From mergers and acquisitions to regulatory changes and technological advancements, we cover all the key developments that impact the industry. Stay tuned for weekly updates to keep you well-informed.

  • Oil prices stable as tariff and Ukraine uncertainty dominates sentiment
  • Summary: Oil prices remained stable on Monday, with Brent crude rising 31 cents to $73.12 per barrel and WTI up 25 cents to $70.01, after posting their first monthly decline since November. Investors monitored geopolitical tensions as Ukrainian President Zelenskiy sought to repair ties with Trump, while U.S. tariffs on Canada and Mexico, set to take effect Tuesday, raised concerns over economic and oil demand growth. Analysts expect Brent to average $74.63 per barrel in 2025, with potential impacts from U.S. sanctions, supply levels, and a possible Russia-Ukraine peace deal.
  • Read more

  1. Congress votes to kill Biden-era methane fee on oil and gas producers
  2. Summary: The Republican-controlled Congress voted to repeal the Biden-era methane fee on oil and gas producers, which was set to charge $900 per ton of excess methane emissions, increasing to $1,500 by 2026. The repeal, passed in a 52-47 Senate vote after a similar House decision, now awaits President Trump’s expected approval, nullifying a key climate policy aimed at cutting 1.2 million metric tons of methane emissions by 2035. While the oil industry praised the repeal as a win for energy production, critics argue it benefits the worst polluters and undermines efforts to curb a potent greenhouse gas.
  3. Read more

  1. US drillers add oil and gas rigs for fifth week in a row, Baker Hughes says
  2. Summary: U.S. energy firms added one oil and gas rig this week, marking the fifth consecutive weekly increase, the longest streak since May 2022, bringing the total count to 593, according to Baker Hughes. Despite this rise, the count remains 36 rigs (6%) lower than a year ago, with oil rigs down by two to 486 and gas rigs up by three to 102. In February, the total rig count increased by 11, the largest monthly gain since November 2022, even as companies plan to cut spending by around 1% in 2025 compared to 2024.
  3. Read more

  • Crude suffers worst month since September
  • Summary: Oil prices dropped nearly 4% in February, marking their worst monthly performance since September, as escalating U.S. tariffs weakened investor confidence and clouded energy demand. West Texas Intermediate (WTI) settled at $69.76 per barrel, down 3.8% for the month, while Brent crude fell to $73.18 per barrel, with the more-active May contract declining to $72.81. The market was further pressured by weak economic data, algorithmic short-selling, uncertainty surrounding U.S.-China-Mexico trade tensions, and the potential restart of pipeline exports from Iraq’s Kurdistan region.
  • Read more

  • Trump’s tariffs threat hits Canada’s oil and gas drillers
  • Summary: Canada’s oilfield drilling sector is slowing due to U.S. President Donald Trump’s proposed 10% tariff on the 4 million barrels per day (bpd) of Canadian crude exported to the U.S., which could stall the industry’s recovery. TD Cowen cut its 2025 Canadian rig count forecast by 5% to 175 active rigs and downgraded stocks like Precision Drilling (PD.TO) and Ensign Energy Services (ESI.TO) from “buy” to “hold.” Retaliatory tariffs from Canada could further raise costs for drilling inputs, such as sand used in hydraulic fracturing, impacting smaller producers more than larger oil companies with set budgets.
  • Read more

  1. U.S. natural gas power expands, complicating climate goals
  2. Summary: A surge in electricity demand from tech companies, particularly those in the AI sector, is driving increased investment in natural gas-fired power plants in the U.S., complicating efforts to reduce greenhouse gas emissions. While some firms are pursuing renewable energy sources like solar, wind, and battery storage, many utilities are favoring natural gas for its cost-effectiveness and reliability. Analysts now predict a larger and longer-lasting role for gas-fired power, with its growth accelerating beyond previous expectations.
  3. Read more

Contact Valor Today

Contact us today if you need help outsourcing your oil and gas operations.

The information provided by Valor in this blog is for general informational purposes only, not to provide specific recommendations or legal or tax-related advice. The blog/website should not be used as a substitute for competent legal advice from a licensed professional attorney in your state.