Ring Energy (REI) Q3 2026 earnings review
Ring Energy sells minor wells, but heavy drilling burns cash
Ring Energy, a Permian Basin oil and gas producer, sold minor properties to buy core land and cut debt, while heavy upfront well spending pushed cash flow negative. Profit excluding one-offs rose 14% from last quarter to $27 million as new regional pipelines nearly wiped out West Texas natural gas pricing losses. However, chief executive Paul D. McKinney overspent the quarterly capital budget by $14 million at the top end to bring the company's first five two-mile horizontal wells online.
| Total sales volume | 20,635 Boe/d +3% from last quarter; -1% from a year ago |
|---|---|
| Profit excluding one-offs | $27.3M ($0.10/sh) +14% from last quarter; +108% from a year ago |
| Free cash flow, excluding one-offs | -$13.8M $64.0M well spending vs $40–$50M plan |
| 2027 volume outlook | Trimmed 2% 22,000 Boe/d middle of range (+12% excluding asset sales) |
⚖️ Verdict: ⚪ Neutral
The standing case is unchanged because smart property deals and better gas pricing balanced out a cash outflow and a slower debt paydown schedule. Selling 600 barrels per day of minor wells for $44 million paid for a 25% larger core drilling footprint and $10 million of debt reduction. The bad news: five of the seven new horizontal wells finished too late in the quarter to prevent an oil volume miss, and finance chief Sundip Singh Johl pushed the target date for hitting the bank debt ratio that relaxes mandatory hedging from early 2027 to late 2027.
The question now is whether the new two-mile multi-well pads can deliver the 2027 plan of 9% production growth on 20% less capital spending by our math. Either the five Crane County wells completed late in the third quarter lift output enough to generate at least $9 million of fourth-quarter free cash flow and keep the full year positive, or pad shut-ins and rapid well declines force another spending raise. Fourth-quarter oil volume and cash flow will tell.
🐂 Bull Case
Asset Sales Funded Core Land and Cut Debt
Ring Energy, a Permian Basin oil and gas producer in Texas, reversed its earlier view that it had no minor properties left to sell. Chief executive Paul D. McKinney said rival drillers offered high prices for deeper acreage that Ring did not plan to drill over the next two years.
- Third-quarter property sales: $30.5 million for 9,800 net acres producing 130 barrels of oil equivalent per day (Boe/d)
- October property sale: $13.4 million for assets producing 470 Boe/d
- Core land bought: $18.8 million for 16,500 net acres in the Central Basin Platform, expanding its footprint in Crane and Ector counties by 25%
- Debt repaid: $10.0 million on the credit line, lowering the balance to $350.0 million
This trade strengthens the business because the sold properties gave up less than 3% of daily output while paying for a 25% larger core drilling area and a $11.7 million net cash surplus in the third quarter by our math. The October sale adds another $13.4 million to cut debt in the fourth quarter.
What to watch: the year-end credit line balance in the annual report. A drop below $335 million would confirm that the October sale proceeds and fourth-quarter cash flow went directly to debt reduction.
New Pipelines Eased Natural Gas Losses
Permian oil wells also bring up natural gas, and pipeline bottlenecks in West Texas forced Ring to pay buyers to take that gas away over the past six quarters. In the second quarter, the producer lost $5.20 for every thousand cubic feet (Mcf) of gas it produced.
Those losses nearly vanished in the third quarter as the average gas price rose by $4.90 to negative $0.30 per Mcf. Finance chief Sundip Singh Johl attributed the rebound to "relief as additional Permian takeaway and processing capacity came online". Because gas loss narrowed and natural gas liquids prices rose 4% to $10.38 a barrel, Ring's total selling price per barrel of oil equivalent fell 6% from last quarter even though crude oil prices dropped 12%.
What to watch: the average natural gas selling price in the fourth quarter. A positive price above zero would show that new pipelines can overcome Ring's processing fees without relying on regional price hedges.
Operating Cash Margin Rose Despite Cheaper Oil
Ring's operating profit before depreciation, taxes, and non-cash items (Adjusted EBITDA) rose 5% from the second quarter to $57.1 million, lifting its margin by 4 percentage points to 56% of revenue. By our math, lower cash payouts on oil price hedges drove the improvement, dropping by 5.7 percentage points of revenue from the second quarter to $12.2 million as crude prices cooled from $95.45 to $83.72 per barrel.
Well upkeep costs (lease operating expenses) held steady at $10.20 per barrel of oil equivalent, down 5% from $10.73 a year ago and removing 7.2 percentage points of revenue compared with last year. Corporate overhead excluding stock pay rose 12% from last quarter to $6.5 million on temporary legal bills, but lower debt cut interest costs by 8%.
What to watch: cash corporate overhead per barrel of oil equivalent in the fourth quarter. A drop back toward $3.20 would confirm Johl's statement that third-quarter legal and professional fees were one-time costs.
🐻 Bear Case
Early Well Spending Pushed Cash Flow Negative
Ring is shifting from single-well pads to drilling multiple two-mile horizontal wells on the same pad to cut costs per foot by 6% to $475. Supporters view this shift as the engine for 2027 growth, as the company completed its first five two-mile wells in Crane County this quarter. However, management "deliberately chose to outspend adjusted free cash flow this quarter to accelerate our program," McKinney said.
- Capital spending: $64.0 million, up 48% from last quarter and $14.0 million above the top of the $40.0–$50.0 million quarterly plan
- Free cash flow, excluding one-offs: negative $13.8 million, leaving nine-month cash flow at negative $9.2 million
- Crude oil sales volume: 12,818 barrels per day, missing the 13,000–13,950 second-half target range
Oil missed because multi-well pads require shutting in nearby wells during completion, and "only 2 of those wells were on early enough to have a measurable contribution to our production this quarter," McKinney told analysts. McKinney still promised that "we intend to be cash flow positive during the fourth quarter and for the full year". By our math, Ring must generate at least $9.2 million of free cash flow next quarter while spending $43–$48 million on wells.
What to watch: fourth-quarter crude oil sales volume against the 12,900–13,500 barrels per day target. A second miss after all five two-mile wells are online would show the new wells are underperforming.
Debt Paydown Timeline Slipped Past Early 2027
Under its bank credit line, Ring must hedge a large portion of its future oil output two years out until its debt ratio falls below 1.25 times annual earnings and its credit line is less than 50% drawn. Last quarter, management said it could hit that goal as early as the first quarter of 2027.
This quarter, the driller highlighted a debt ratio of 1.5 times based on annualising the third quarter alone, while the trailing twelve-month ratio used by its banks stood higher at 1.87 times. With $350 million drawn on the $585 million credit line (60% used by our math), Johl admitted Ring is "not quite at the leverage metric we need to be" and pushed the target back to the second half of 2027 at $75 oil.
What to watch: the outcome of the December bank borrowing base review. A lower credit limit or unchanged covenant rules would lock Ring into mandatory two-year oil hedges through late 2027.
Swaps Cap Oil Gains While Dilution Bites
Management remains optimistic on oil prices due to Middle East supply risks, and sold 30% higher oil prices than a year ago at $83.72 per barrel. However, to protect its front-loaded 2027 drilling budget, Johl added fixed-price oil swaps to "ensure we remain free cash flow positive even at $65 WTI".
Ring now has 59% of its expected oil output for the first half of 2027 locked into swaps at about $67 to $71 per barrel, up from roughly 38% hedged for 2027 last quarter. That gives away price upside above $71 on most of its oil just as shareholders absorb a 26% higher diluted share count from last quarter's stock offering, which kept profit per share excluding one-offs unchanged from the second quarter at $0.10 despite 14% higher profit.
What to watch: cash paid on derivative settlements in the fourth quarter, where 81% of oil is hedged at an average ceiling of $74.10. Continued multi-million-dollar payouts would show hedges are still absorbing the oil rally.
Risks This Quarter Didn't Answer
Three standing risks received no quantitative update in the third-quarter earnings release or call.
- Individual two-mile well production rates: management declined to give flow rates for the new Crane County wells because it is "actively leasing, so we do not wanna release exactly where we are active", leaving well economics unproven until 2027.
- Customer concentration: Phillips 66 accounted for 75% of revenue in the second quarter; the third-quarter filing is required to see if buyer reliance rose further.
- Property write-down risk: Ring recorded zero impairment this quarter after $271 million of write-downs over the prior three quarters, but lower oil prices would trigger new charges under full-cost accounting.
💲 Other KPIs
Swung from a $64.8 million net profit in the second quarter to a $16.6 million loss, though narrower than the $51.6 million loss a year ago. A $41.0 million non-cash accounting loss on future commodity hedges caused the swing as forward oil and gas prices moved higher at quarter-end.
Bills owed to suppliers and drilling contractors rose 30% from $90.3 million at year-end 2025, adding $20.1 million to operating cash flow in the third quarter alone. The buildup reflects the jump to $64.0 million in quarterly well spending and will drain cash as those drilling bills are paid in the fourth quarter.
Interest costs dropped 24% from $10.1 million a year ago and 8% from $8.4 million in the second quarter. On a per-barrel basis, interest fell 23% over the past year from $5.26 to $4.05 after the producer cut total debt by $88.2 million using stock offering proceeds and property sales.
🔮 Guidance
Cut. The middle of the range is 20,800 Boe/d, up 0.8% from the third quarter and 1.4% from a year ago, but 400 Boe/d below the prior second-half midpoint after selling 600 Boe/d of non-core properties. Adjusted for those sales, underlying fourth-quarter output grows 4.4% from a year ago by our math, leaving full-year 2026 average volume at about 20,200 Boe/d.
Cut. The 13,200 Bo/d midpoint rises 3.0% from the third quarter as five new Crane County wells contribute for a full period, and sits 0.6% above last year. By our math, that leaves full-year 2026 oil sales at 12,747 Bo/d, near the bottom of what the prior outlook implied.
Raised. Spending drops 29% from the third quarter's $64.0 million peak to $45.5 million at the middle of the range, but pushes second-half spending to $109.5 million versus the prior $80–$100 million plan. By our math, full-year 2026 capital spending reaches $187.2 million, the second straight raise after moves of +$0M, +$52.7M, and +$19.5M.
Lowered cost target. The $10.05 midpoint improves 1.5% from the third quarter's $10.20 as higher pad volume spreads fixed field costs across more barrels. Ring has beaten its quarterly cost midpoint for four straight quarters by an average of 5.4%; if the pattern holds, fourth-quarter lease operating expense would land near $9.51 per Boe by our math.
Trimmed for asset sales. Management lowered both ends of the range by 500 Boe/d after selling 600 Boe/d of non-core production in the second half of 2026. At the 22,000 Boe/d midpoint, total output grows 8.9% over implied 2026 levels by our math, or 11.9% on a like-for-like basis excluding the sold wells.
Trimmed for asset sales. The 13,750 Bo/d midpoint is down 350 Bo/d from the initial target to remove the oil portion of the sold properties. By our math, the updated plan still calls for 7.9% oil growth over implied 2026 production.
Unchanged. The $150.0 million midpoint represents a 20% spending cut from the $187.2 million implied for full-year 2026 by our math, while still drilling 20 to 30 horizontal wells longer than 1.5 miles. Management plans to concentrate this budget in the first half of 2027 and adjust second-half drilling based on oil prices.
Lowered cost target. The range moved down $0.10 per Boe after Ring sold higher-cost vertical wells, putting the $10.10 midpoint slightly below the $10.24 nine-month average in 2026.
❓ Key Questions
What are the flow rates on the two-mile wells?
Ring completed five two-mile wells in Crane County, but only two came online early enough to help third-quarter oil volume, which missed the target range. Investors need 30-day or 60-day production rates to verify that longer wells can deliver 9% growth on 20% less capital.
How much more non-core acreage is up for sale?
After raising $43.9 million from property sales in the third quarter and October to fund core land and debt paydown, McKinney called asset recycling an ongoing part of the strategy. Management did not say how many remaining acres fail to compete for near-term drilling capital.
When will Ring disclose its five new horizontal zones?
Executives said they have now proven five horizontal rock layers in the Central Basin Platform, up from two last year, but withheld the zone names and locations while leasing land. Knowing the depths and rock quality is necessary to judge how many of the 16,500 new acres are drillable.
Did buyer concentration with Phillips 66 change in Q3?
Phillips 66 bought 75% of Ring's oil and gas in the second quarter, up from 65% a year earlier. Because the full quarterly filing was not included with the release, the current single-buyer credit and pipeline reliance is not yet readable.