Helmerich & Payne, Inc.

Helmerich & Payne, Inc. (HP) Market Cap

Helmerich & Payne, Inc. has a market capitalization of —.

No quote data available.

CEO: Raymond John Adams

Sector: Energy

Industry: Oil & Gas Drilling

IPO Date: 1980-10-15

Website: https://www.hpinc.com

Helmerich & Payne, Inc. (HP) - Company Information

Market Cap: -|Sector: Energy

Company Profile

Helmerich & Payne, Inc., along with its affiliated companies, provides specialized drilling services and innovative solutions to businesses involved in the exploration and production of oil and gas. The company's operations are strategically organized into three distinct divisions: North America Solutions, Offshore Gulf of Mexico, and International Solutions. Within the North America Solutions segment, primary drilling activities are conducted across a broad geographical area, encompassing U.S. states such as Colorado, Louisiana, Montana, Nevada, New Mexico, North Dakota, Ohio, Oklahoma, Pennsylvania, Texas, Utah, West Virginia, and Wyoming. This division also actively pursues the development, promotion, and commercialization of advanced technologies designed to enhance drilling efficiency, wellbore quality, and accurate placement. The Offshore Gulf of Mexico segment focuses its drilling endeavors in Louisiana and within the federal waters of the U.S. Gulf of Mexico. Internationally, the Solutions segment manages drilling projects in various countries, including Argentina, Bahrain, Colombia, and the United Arab Emirates. As of September 30, 2021, Helmerich & Payne commanded a substantial fleet, featuring 236 land rigs situated in North America, 30 land rigs operating internationally, and 7 offshore platform rigs. Beyond its core drilling operations, the company also maintains an interest in commercial real estate. Its property portfolio in Tulsa, Oklahoma, comprises a shopping center offering approximately 390,000 square feet of leasable space, alongside about 176 acres of undeveloped land. Helmerich & Payne, Inc. was founded in 1920 and continues to maintain its corporate headquarters in Tulsa, Oklahoma.

Analyst Sentiment

67%
Buy

From 16 Active Polls

1Y Forecast: $39.83

▲ +0.0% Potential Upside

Consensus Target Metrics

Low Bound

$36

Median

$40

High Bound

$43

Average

$40

Price & Moving Averages

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🎯 Wall Street Analyst Intelligence Report

1-Year structural target targets, chart projections, and sentiment maps.

Average 1Y Target
$39.83
▲ +15.22% Upside
Low Target
$36.00
4% Risk
Median Target
$40.00
16% Mid
High Target
$43.00
24% Max

Consensus Trend Projection

Trailing closures vs. 12-month metrics map.

Analyst Vote Distribution

Aggregate institutional coverage sentiment weights.

Sentiment volume allocation data unavailable.

valuation & financial ratiosdetailed financials

Historical valuation matrix unavailable.

📘 Full Research Report

ℹ️

AI-Generated Research: This report is for informational purposes only.

📘 HELMERICH & PAYNE INC (HP) — Investment Overview

🧩 Business Model Overview

Helmerich & Payne operates in U.S. land drilling, supplying drilling rigs and associated services to exploration and production (E&P) customers. The value chain centers on (1) owning and maintaining a rig fleet, (2) deploying rigs to customer drilling programs, and (3) running contracted operations through field crews and operating systems.

Customer stickiness typically comes from operational execution, schedule reliability, and rig customization. When E&P operators commit to a drilling plan, the provider that can deliver the right rig configuration, safety performance, and drilling efficiency—while minimizing downtime—becomes a repeat vendor across well programs and basins.

💰 Revenue Streams & Monetisation Model

HP monetizes primarily through day-rate and contract-based revenue for drilling services. Revenue is largely transactional by nature (tied to active drilling days), but margin durability is influenced by how effectively the company matches rig availability to customer demand and how efficiently it operates and maintains its fleet.

Key margin drivers include:

  • Rig utilization: higher utilization spreads fixed operating and fleet costs over more revenue-producing days.
  • Fleet mix: exposure to automation-capable and higher-performance rigs can support premium economics when demand supports it.
  • Operating efficiency: labor productivity, maintenance discipline, and uptime directly impact contribution margin.
  • Contract structure: day-rate and duration terms determine how much day-to-day commodity-cycle pressure flows through to HP.

🧠 Competitive Advantages & Market Positioning

HP’s moat is most defensible on technical differentiation and operational execution rather than on low-cost inputs. The company’s fleet and systems are designed to improve drilling control and efficiency, which can matter in tight operational environments where well schedules and wellbore quality drive downstream economics.

  • Intangible/technology moat (automation and control systems): HP emphasizes advanced rig control and automation (including its IntelliTrac technology), which can improve precision, reduce non-productive time, and support consistent drilling performance.
  • Switching/friction economics: while drilling services are not “software-like,” customers face practical switching costs—rig qualification, mobilization planning, operating procedures, and crew familiarity. Providers with consistently reliable performance tend to be reused across drilling programs.
  • Fleet scale and maintenance depth: maintaining a capable fleet through cycle troughs supports faster redeployment when activity returns, improving competitive position versus smaller or less flexible operators.

Competitive benchmarking: HP competes with other land rig contractors such as Patterson-UTI Energy and Nabors Industries for U.S. onshore drilling demand. These peers also offer land drilling capacity and automation options, but HP’s positioning has been more concentrated on automation-forward rigs and delivering measurable drilling performance. HP additionally faces competition from a broader service ecosystem including major contractors and integrated service providers that can bundle equipment and services, which can shift customer sourcing decisions during different activity regimes.

🚀 Multi-Year Growth Drivers

Over a 5–10 year horizon, HP’s growth prospects are driven more by industry activity and well construction complexity than by a permanently expanding service TAM. The structural tailwinds are nevertheless relevant:

  • Ongoing unconventional resource development: continued appraisal, development, and infill drilling sustains demand for land rigs, even as the industry cycles through capital allocation phases.
  • Operational efficiency requirements: E&P operators increasingly prioritize drilling speed, downtime reduction, and consistent well construction, which supports demand for higher-spec, automation-enabled rigs.
  • Regional basin development depth: basins that require sustained drilling programs can support repeat contracting, especially when infrastructure and logistics favor established rig operators with proven mobilization capability.
  • Potential for share gains during utilization rebounds: fleet redeployment strength can translate into improved market share when activity rises, assuming HP maintains operational performance and fleet readiness.

⚠ Risk Factors to Monitor

  • Commodity-cycle and customer capex volatility: drilling services are cyclical; utilization and day rates can compress materially when E&P spending contracts.
  • Capital intensity and fleet impairment risk: owning and upgrading rigs requires sustained capex and can lead to stranded or impaired asset value during prolonged downturns.
  • Competitive technology convergence: automation features and performance improvements can be replicated by competitors over time, narrowing differentiation.
  • Safety, regulatory, and operational execution: drilling environments carry high safety and regulatory exposure; operational lapses can impact contract retention and cost structure.
  • Customer concentration and contract leverage: when E&P buyers consolidate vendors, negotiating leverage can shift toward customers during weaker demand periods.

📊 Valuation & Market View

The market typically values land drilling contractors on cash generation capacity through the cycle, often using EV/EBITDA and other cash-flow-oriented frameworks rather than pure revenue multiple measures. Valuation swings are primarily driven by:

  • Utilization and day-rate outlook: expectations for how quickly rigs can be absorbed by customer drilling programs.
  • Operating leverage: whether fixed-cost discipline and fleet uptime hold up as activity changes.
  • Balance sheet resilience: net debt, liquidity, and how management navigates downturns without impairing long-term fleet economics.
  • Fleet strategy and asset quality: how effectively advanced rigs maintain a premium versus conventional alternatives.

🔍 Investment Takeaway

Helmerich & Payne’s long-term case rests on an operational and technical differentiation moat—automation-enabled rig capability, execution reliability, and fleet readiness—paired with the ability to earn structurally better economics when market activity supports premium performance. The investment thesis remains inherently cyclical due to customer drilling behavior, so risk-adjusted returns depend on fleet discipline, balance-sheet durability, and maintaining differentiation as competitors offer comparable capabilities.


⚠ AI-generated — informational only. Validate using filings before investing.

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📊 AI Financial Analysis

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Earnings Data: Q Ending 2026-03-31

"HP reported Q2/FY2026 revenue of $932.4M and net loss of -$58.6M (EPS: -$0.59). QoQ, revenue fell -8.3% (from $1.017B in 2025-12-31) while net loss widened to -$58.6M from -$97.2M (an improvement in losses). YoY, revenue declined -8.2% versus $1.016B in 2025-03-31, and net income deteriorated sharply from +$1.7M to -$58.6M. Profitability weakened over the quarter-to-quarter comparison: gross margin contracted materially to 7.0% from 11.9% in the prior quarter, and operating margin remained negative at -1.3% (down from +4.3% in Q1). Cash generation was modestly positive but not sufficient to offset losses: operating cash flow was +$36.6M and free cash flow was -$26.3M, with dividends paid of -$25.4M. Over the 4-quarter period, balance-sheet resilience appears mixed but generally stable for a large-cap: total assets were $6.34B and total stockholders’ equity was $2.53B, while net debt remained elevated at ~$1.80B. Shareholder returns look strong based on market momentum: price is up +71.2% over 1Y. With a low dividend yield (~0.7%), total return is being driven primarily by capital appreciation rather than income. Analyst targets (consensus ~$36.86) are below the current price ($33.64), suggesting near-term upside is limited versus recent momentum."

Revenue Growth

Caution

Revenue declined QoQ by -8.3% (from $1.017B) and declined YoY by -8.2% (vs. $1.016B), indicating a weakening top line.

Profitability

Neutral

Margins contracted: gross margin fell to 7.0% from 11.9% QoQ. Net income shifted from a small profit YoY (+$1.7M to -$58.6M) and remained negative.

Cash Flow Quality

Fair

Operating cash flow was positive (+$36.6M) but free cash flow turned negative (-$26.3M) in Q2. Dividends were paid (-$25.4M) despite net losses.

Leverage & Balance Sheet

Neutral

Equity is sizable ($2.53B) and total assets are $6.34B; however leverage remains meaningful with net debt around $1.80B and debt at ~$2.00B.

Shareholder Returns

Good

Strong price momentum: +71.2% 1Y change materially boosts total return prospects. Dividend yield is low (~0.7%), so returns are driven mainly by appreciation.

Analyst Sentiment & Valuation

Neutral

Consensus target (~$36.86) is modest relative to recent run-up; the current price context suggests limited incremental upside despite strong momentum.

Disclaimer:This analysis is AI-generated for informational purposes only. Accuracy is not guaranteed and this does not constitute financial advice.

RevenueEarningsP/E RatioSharesDebtMargin %

Fundamentals Overview

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Helmerich & Payne reported resilient Q2 fundamentals with solid adjusted EBITDA of $178M, but profitability was pressured by Middle East disruption and accounting classification shifts (reactivation CapEx moved to OpEx). International Solutions direct margin was $11.5M at the low end of guidance, with incremental quarterly direct margin impact of ~$3.5M tied to crisis response, supply chain inflation, slower drilling restart, and Iraq suspension; guidance further embeds a ~$6M midpoint risk to Q3 if the Strait of Hormuz remains effectively closed. North America showed clear inflection early: average 136 rigs, direct margin tapering to $17,600/day, and guidance raised—Q3 direct margins of $230M–$240M with 137–143 rigs, plus full-year NAS rig count increased to 138–144. Catalysts center on tight Lower 48 DUC dynamics, super-spec utilization >80%, and FlexRobotics scaling (4 additional systems planned). Balance sheet momentum (term loan repaid ahead of schedule; $350M bond focus) improves flexibility, though higher cash taxes and working-capital effects reduce near-term free cash flow conversion.

AI IconGrowth Catalysts

  • FlexRobotics: first rig now operating its fifth pad for a super major customer in the Permian Basin; planned deployment of additional 4 FlexRobotics systems with first 3–4 systems expected operational this calendar year
  • Lower 48 tightening: expectation that Q2 is the trough for both rig count and direct margins; anticipated steady increase in drilling activity to exhaust ~2,000 DUC locations
  • Super-spec reactivation capacity: ~20 idle super-spec rigs estimated to be reactivated at maintenance CapEx levels, supporting market share gains
  • International recovery: Latin America Vaca Muerta utilization ramp toward 100% with 12 rigs targeted; Saudi Arabia reactivations continuing with 6 of 7 rigs expected reactivated by end of the quarter

Business Development

  • Offshore Solutions: 5-year BP contract extension in the Caspian Sea (3 additional 1-year extension options)
  • Middle East: 6-year contract extension covering 5 rigs in Oman
  • Argentina: Vaca Muerta activity accelerated driven by host NOC and domestic independents (9 rigs operating; path to 12 rigs active)

AI IconFinancial Highlights

  • Revenues: $932 million (Q2)
  • Adjusted EBITDA: $178 million, aligned with lower end to midpoint of implied guidance; driven by Middle East conflict impacts mitigated via in-house engineering/aftermarket reactivations in Saudi Arabia
  • EPS: net loss of $0.59 per diluted share; impacted by noncash impairment charge of ~$26 million; adjusted/absent items loss was $0.38 per share
  • International Solutions direct margin: $11.5 million, at lower end of guidance range; ~$3 million impact from classifying rig reactivation CapEx as OpEx
  • International conflict cost estimate: ~$3.5 million impact to direct margins in the quarter (crisis management response, supply chain inflation, slower drilling start, rig suspension in Iraq)
  • Guidance impact if Strait of Hormuz remains effectively closed: midpoint ~$6 million direct margin impact to Q3 results (inclusive of Iraq and Bahrain rig suspensions)
  • North America Solutions direct margin taper: $17,600 per day; direct margin for NAS segment $215 million, near midpoint
  • Capital expenditures Q2: $63 million, below anticipated levels due to CapEx-to-OpEx reclassification, resequencing into Q3/Q4, and improved capital efficiency
  • Free cash flow: negative in-quarter driven by timing lag between receivables collections and payables disbursements; excluding working capital changes, free cash flow was $74 million

AI IconCapital Funding

  • Deleveraging milestone: sale proceeds enabled full repayment of remaining term loan $400 million ahead of schedule
  • Liquidity: cash and short-term investments ~$199 million; total liquidity ~$1.15 billion including revolver availability
  • Debt repayment focus: $350 million bond due end of 2027; plan to build cash and repay ahead of schedule while maintaining base dividend
  • Capital allocation framework: maintain investment-grade status as top priority; balance deleveraging with high-return investment opportunities as drilling activity increases
  • Cash taxes outlook (post Utica Square sale): $125 million to $150 million (higher than previously anticipated)

AI IconStrategy & Ops

  • Middle East execution: reactivated rigs in Saudi Arabia using in-country equipment to circumvent supply chain constraints; however, increased OpEx via reclassification of reactivation CapEx
  • Rig disruptions: 1 rig suspension in Iraq during the quarter; notification of suspension of 2 rigs in Bahrain for up to 90 days
  • Reactivation pace: spudded 3 of 7 Saudi rigs; 2 more expected to commence drilling imminently; 6th rig anticipated active later in the quarter and 7th rig following next quarter
  • North America operating fleet: averaged 136 contracted rigs in Q2; exited at 137 rigs; as of last week 138 rigs were working
  • Backlog/contract mix improvement: over 55% of operating fleet on term vs spot, up from just over 50% in the prior quarter
  • SG&A optimization: reduced SG&A by >$50 million vs premerger stand-alone run rates; continued harmonization across Western and Eastern Hemisphere operations

AI IconMarket Outlook

  • North America Solutions Q3 direct margin: $230 million to $240 million on anticipated rig count of 137 to 143 rigs
  • Full-year NAS rig count range raised: 138 to 144 rigs; expects positive inflection in margin rates; confirms Q2 as trough
  • International Solutions Q3 rig count: 58 to 68 rigs (also implied for full year); expects direct margin $12 million to $32 million
  • International Solutions cost midpoint assumption for Q3: ~$6 million direct margin impact if Strait of Hormuz effectively closed for duration of quarter
  • Offshore Solutions Q3: 30 to 35 average management contracts and operating rigs; direct margin rate $24 million to $28 million; expects step back up and remain confident in $100 million to $115 million direct margin full-year guidance
  • 2026 gross CapEx budget updated: align with high end $270 million to $310 million; Q3 spending expected $100 million to $130 million (excludes additional reactivations beyond announced; includes only 4 FlexRobotics packages beginning deployment this year)
  • Free cash flow conversion: expected trend lower for the year due to higher cash taxes/capex/working capital outflows, but still an improvement vs prior year

AI IconRisks & Headwinds

  • Middle East conflict: supply chain constraints and crisis-management costs; classifying rig reactivation CapEx as OpEx impacts direct margins
  • Strait of Hormuz risk: guidance includes potential ~$6 million midpoint direct margin impact to Q3 if the Strait remains effectively closed
  • Rig suspensions: interruptions in Iraq (1 rig) and Bahrain (2 rigs suspended up to 90 days)
  • OFS softness earlier in fiscal year transitioning to tightening: near-term activity could be temporary and subject to operator drawdown timing
  • Capital timing/working capital: rare timing lag caused negative free cash flow during the quarter; could recur if collections/disbursements mismatch

Q&A: Analyst Interest

  • NAS recovery path & margin progression: Management reiterated Q2 as the trough, citing forward strip improvement pre-conflict, private E&P pickup, and early public-customer signaling; they tied rig-count ramp to DUC exhaustion (~2,000 locations), tight super-spec utilization, and near-term upcycle conditions.
  • Rig count implied mid-140s: Management linked higher-than-previous rig-count expectations to private/independent operator pickups plus early signs from public E&Ps; they emphasized constrained super-spec market capacity, noting 65 estimated idle rigs that could return within 6 months at $1M–$4M CapEx and their ~20 maintenance reactivation tranche.
  • Operational differentiation in reactivations: Lennox quantified performance from third-party Delaware Basin analysis—4.6 days ahead by the first well and 5.3 days by the 10th well versus competitors; he framed this as planning/engineering-driven value that supports ability to scale as demand rises.

Sentiment: MIXED

Note: This summary was synthesized by AI from the HP Q2 2026 earnings transcript. Financial data is complex; please verify all metrics against official SEC filings before making investment decisions.

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© 2026 Stock Market Info — Helmerich & Payne, Inc. (HP) Financial Profile