Key Highlights

● Total output averaged about 1,034,000 barrels of oil equivalent per day in the third quarter.

● Free Cash Flow topped $2 billion for the quarter.

● The base Dividend rose more than 7% to $1.18 per share.

● Diamondback acquired a 7.5% Equity interest in the Solitude Natural Gas pipeline.

Diamondback Energy (NASDAQ:FANG) reported third-quarter results on the second of November, showing another quarter of production above 1 million barrels of oil equivalent per day and lifting its full-year guidance for the second time in as many reports. Oil output averaged about 525,000 barrels per day, total output reached roughly 1.034 million barrels of oil equivalent per day, and free cash flow topped $2 billion.

The release came with a series of balance-sheet and distribution announcements. The base dividend was raised by more than 7%, the company continued acquiring its own shares at a measured pace, it redeemed its maturing senior notes at par and it retired some longer-dated notes below face value. It also disclosed a 7.5% equity interest in the Solitude Pipeline System, a natural gas line that carries Permian gas toward the Katy hub near Houston.

The results arrive at a time when Permian producers have been wrestling with weak local natural gas prices, high oil prices linked to Middle East disruption and questions about how fast to grow. Readers following Oil and Gas Stocks will find the report a useful snapshot of a large independent producer that is raising output while insisting on Debt reduction. The sections below review the numbers, the pipeline stake and the guidance changes, reporting only what the company and published coverage have said.

What were the headline numbers for the quarter for Diamondback Energy?

Net Earnings attributable to Diamondback were about $1.6 billion, or $5.69 per diluted share. Adjusted net earnings, which strip out items the company regards as unusual, were slightly higher at about $1.65 billion, or $5.86 per diluted share.

Operating cash flow before Working Capital changes was about $3.2 billion, and net cash from Operating Activities was about $2.6 billion. After roughly $1 billion of cash capital spending, free cash flow came to a little over $2.1 billion, and the company reported adjusted free cash flow of about the same amount.

The company did not include a chief executive Quotation in the release itself, leaving the table of figures and the revised guidance to carry the message. The call took place the following morning.

How did production compare with the prior quarter?

The second-quarter report in August had been the first in the company's history to top 1 million barrels of oil equivalent per day, at about 1.018 million. The third quarter extended that, with oil at about 525,000 barrels per day and total output at about 1.034 million, comfortably inside the range management had offered three months earlier.

All activity in the quarter took place in the Midland Basin. Crews drilled a little over 100 gross wells and completed a little over 135, and the average completed lateral length was a bit more than 13,500 feet. The busiest zones were the Wolfcamp A, the Wolfcamp B, the Lower Spraberry and the Jo Mill, which shows the company is drawing on several layers of rock instead of relying on one.

Well counts and lateral length are worth tracking because longer laterals typically lower the cost per foot drilled and allow each well to drain more rock. A figure of more than 13,000 feet is long by historical standards, and it signals that the company continues to design larger development projects in the Midland Basin. The fourth-quarter budget range, a little over $1 billion, implies activity will stay roughly at the third-quarter level rather than accelerate or fall sharply.

What changed in the full-year guidance for Diamondback Energy?

Full-year oil production is now expected around 524,000 barrels per day, up from at least 522,000, while total production is guided to about 1.015 million barrels of oil equivalent per day, up from at least 1 million. The fourth quarter is expected to be flat to slightly higher for oil, in a band running from 518 to 528,000 barrels per day.

Spending moved up too. Total Capital Expenditure for the year is now between $3.95 billion and $4 billion, compared with about 3.9 billion previously, and the operated drilling and completion budget was nudged higher. Fourth-quarter capital is guided to between $1 billion and $1.05 billion. The company also narrowed its Lease Operating Expense range and lowered its guidance for gathering, processing and transportation costs and for production taxes as a share of revenue.

Why did the company take a stake in a gas pipeline?

The Solitude Pipeline System moves natural gas from the Permian Basin to Katy, Texas. Diamondback took a 7.5% equity interest. Natural gas has been the weak spot in the Permian for much of this year: the company reported a realized gas price of just over $1 per thousand cubic feet in the third quarter, and its second-quarter realization was actually negative because of constrained takeaway and maintenance work near the Waha hub in West Texas.

A stake in a pipeline does not fix local gas pricing on its own, but it gives the company an economic interest in new capacity and can help secure space for its own molecules. Extra takeaway has been the consistent answer to the Waha problem, and the company also carries basis hedges that extend into next year, according to its August filings. The size of the pipeline stake was not given in dollar terms in the materials reviewed.

Index membership is a background detail, as the company is a constituent of the S&P 500, and the stock trades on the Nasdaq exchange.

How is the company handling debt for Diamondback Energy?

Consolidated total debt stood at about $13.4 billion at the end of September, with net debt about 12.8 billion. Standalone Liquidity was about $3.55 billion, made up of cash and an undrawn Credit Facility of $3 billion.

Management acted on the debt in several ways. On the first of October it redeemed all of its maturing senior notes at par, a payment of nearly $700 million. During the quarter it acquired a portion of its longer-dated notes in the open market at a weighted average of roughly 95% of par, and after the quarter closed it acquired a further Tranche at about 91% of par. Retiring debt below Face Value reduces the interest bill ahead and lowers the amount owed in one step.

Why does Waha pricing matter so much to Permian producers?

The Waha hub in West Texas is where a large share of Permian natural gas changes hands, and when pipelines out of the basin are full or under maintenance the price there can fall below zero. Producers whose wells emit gas alongside oil, known as associated gas, must still move it, so they sometimes pay to have it taken away. That is how a company with strong oil prices can still report a negative realized gas price in a quarter.

For Diamondback the effect is limited by the fact that oil is the dominant Revenue source, but it is not trivial in a Business producing a million barrels of oil equivalent per day. A realized gas price of just over a dollar, as reported for the third quarter, is a markedly improved level compared with the negative figure of the second quarter, which indicates that some of the takeaway pressure eased.

New pipelines scheduled to come online over the next few years are widely expected to ease the bottleneck. A minority interest in one of them gives Diamondback both the benefit of capacity and a share in the tolls other shippers pay, so the stake works as a modest hedge against its own exposure to local gas prices.

What did the company do with cash for owners?

The base quarterly dividend was set at $1.18 per share, an increase of more than 7% from the prior quarter and about 18% above a year earlier. It is payable on the nineteenth of November to owners of record on the twelfth. On an annualized basis the dividend is $4.72.

In the quarter the company acquired about 1.33 million of its own shares for roughly $250 million at an average price a little under $186. In the first weeks of the fourth quarter it acquired nearly 400,000 more for about $73 million. Total cash distributed to owners in the quarter, including dividends, was about $582 million. Management said it expects to continue acquiring shares opportunistically, funded by cash, free cash flow and proceeds from any asset disposals.

What were realized prices and costs?

The realized oil price averaged just over $87 per barrel before hedges and about $86 after hedges. Natural gas realized only a little over $1 per thousand cubic feet, and natural gas liquids realized about $20 per barrel. The blended price was about $51 per barrel of oil equivalent.

Total cash operating expense was about $11 per barrel of oil equivalent. The guidance for lease operating expense remains between roughly $6.06 dollars and $0.20, a slightly tighter band than before, and gathering, processing and transportation costs are now expected to fall between $1.30 and $1.50. These are the line items that determine how much of each barrel's price reaches the bottom line, and the movement in guidance was modestly favorable.

What does the affiliated mineral company expect?

Viper Energy, the mineral and Royalty company affiliated with Diamondback, also supplied guidance. Full-year net production is expected between 137 and 138,000 barrels of oil equivalent per day, with oil at roughly 67,000 barrels per day. Those figures sit above the ranges Viper offered with the second-quarter report.

The relationship matters because royalty and mineral interests benefit from drilling activity on the underlying acreage without the operating costs of drilling. Viper's higher guidance mirrors the increased activity at Diamondback, which operates a large share of the wells on the land Viper owns.

What is the connection between hedges and realized prices?

The company reported a realized oil price of just over $87 per barrel before hedges and about $86 after them, so hedging reduced the figure slightly during the quarter. Hedges set a floor or fixed price for a share of volumes, which sacrifices some upside when prices rise but protects cash flow if they fall.

The gap between unhedged and hedged prices was therefore small in the third quarter, a sign that the portion of production covered by derivative contracts is not large relative to total output. Natural gas basis swaps, on the other hand, cover a large share of Waha exposure through the end of this year and a smaller share in the next.

How the company adjusts its hedge book as prices stay elevated is a recurring question on earnings calls, and the answer influences how much of any further price strength reaches reported earnings.

How did acquisitions affect the quarter?

Property acquisitions in the third quarter totaled about $1.15 billion, and for the first nine months they were about 1.9 billion. The release did not detail every transaction, though the pipeline interest is the one it highlighted.

The size of the acquisitions line shows that the company is still adding to its asset base while it reduces debt. In August it also noted proceeds from asset disposals of several hundred million dollars for the year to date, so the pattern is one of continuously Rebalancing the portfolio instead of keeping a static group of assets.

What themes have run through the company's year?

In the first-quarter report in early May, chief executive Kaes Van't Hof called a production level of about 521,000 barrels of oil per day the new baseline and said that if now was not the time to grow, he did not know when it would be. He referred to a genuine imbalance between Supply and Demand tied to the conflict in the Middle East. The company then lifted guidance in May, August and again this month.

That cadence of raising guidance each quarter, paired with a larger authorization for acquiring its own shares (doubled in August to $16 billion with roughly $10 billion remaining), provides context for the third-quarter numbers. It shows a producer that has chosen to grow output modestly when Commodity prices are favorable while keeping capital discipline and reducing leverage.

What should readers watch from here for Diamondback Energy?

The next markers are the fourth-quarter production range, the dividend payment on the nineteenth of November and any further disclosure about the Solitude interest or other Midstream arrangements. The company also has maturing notes to manage in later years, and further open-market debt reductions are possible if bond prices stay below par.

Commodity prices remain the dominant variable. The company guided on realized prices that are elevated by geopolitical disruption, and a change in the Middle East situation or in OPEC and its partners' output decisions would influence cash flow.