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., together with its subsidiaries, provides drilling services and solutions for exploration and production companies. The company operates through three segments: North America Solutions, Offshore Gulf of Mexico, and International Solutions. The North America Solutions segment drills primarily in Colorado, Louisiana, Montana, Nevada, New Mexico, North Dakota, Ohio, Oklahoma, Pennsylvania, Texas, Utah, West Virginia, and Wyoming. It also focuses on developing, promoting, and commercializing technologies designed to enhance the drilling operations, as well as wellbore quality and placement. The Offshore Gulf of Mexico segment has drilling operations in Louisiana and in U.S. federal waters in the Gulf of Mexico. The International Solutions segment conducts drilling operations in Argentina, Bahrain, Colombia, and the United Arab Emirates. As of September 30, 2021, the company operated a fleet of 236 land rigs in North America; 30 international land rigs; and 7 offshore platform rigs. It also owns, develops, and operates commercial real estate properties. The company's real estate investments include a shopping center comprising approximately 390,000 leasable square feet; and approximately 176 acres of undeveloped real estate located in Tulsa, Oklahoma. Helmerich & Payne, Inc. was founded in 1920 and is headquartered in Tulsa, Oklahoma.

Analyst Sentiment

67%
Buy

From 16 Active Polls

1Y Forecast: $39.43

▲ +0.0% Potential Upside

Consensus Target Metrics

Low Bound

$34

Median

$39

High Bound

$43

Average

$39

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
$39.43
▲ +5.26% Upside
Low Target
$34.00
-9% Risk
Median Target
$39.00
4% Mid
High Target
$43.00
15% 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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H&P reported Q2’26 resilient results despite Middle East disruption that shifted reactivation spending from CapEx to OpEx and caused direct margin pressure. Adjusted EBITDA was $178 million (lower-end to midpoint guidance), while EPS loss of $0.59 reflected a ~$26 million noncash impairment. Operationally, North America averaged 136 contracted rigs (trough dynamics confirmed), with direct margin $215 million near the midpoint and expectations for improving NAS 2H’26. FlexRobotics is a central growth lever: management plans 4 additional deployments, with early systems operational in calendar 2026, and targets continued adoption driven by tight super-spec capacity. International Solutions faced rig suspensions (Iraq; Bahrain up to 90 days) and conflict-related costs; management expects an incremental ~$6 million direct margin impact in Q3 if the Strait of Hormuz remains effectively closed. Capital allocation advanced: Utica Square sale exceeded $100 million and enabled full term-loan repayment, improving liquidity (~$1.15B) and supporting the multiyear upcycle outlook for onshore and offshore demand.

AI IconGrowth Catalysts

  • North America (Lower 48) activity recovery: expect NAS margins and operated rig count growth in 2H’26 as activity ramps from DUC drawdowns and tight super-spec supply
  • FlexRobotics scale-up: deploy additional 4 systems; first 3–4 systems expected operational in calendar 2026
  • International momentum in Latin America: Vaca Muerta accelerated operations (9 rigs operating, path to 12 and 100% utilization)
  • Offshore contract tailwind: BP Caspian Sea extension renewal potentially >$1B revenues if options exercised; performance-contract elements improving offshore direct margin profile

Business Development

  • BP (Caspian Sea): contract extension (firm 5-year term; 3 additional 1-year extension options)
  • Oman (International Solutions): 6-year contract extension covering 5 rigs
  • Permian Basin: FlexRobotics first rig operating its fifth pad; performance described as “straight out of the gates” for a super major customer
  • Saudi Arabia: reactivations enabled via in-country equipment and in-house engineering/aftermarket capabilities
  • Latin America: Vaca Muerta expansion driven by host NOC and domestic independents

AI IconFinancial Highlights

  • Revenues: $932 million
  • Adjusted EBITDA: $178 million, aligned with lower end to midpoint of implied guidance
  • EPS: net loss of $0.59 diluted; impacted by ~$26 million noncash impairment; loss would have been $0.38 per share absent those items
  • Direct margin impacts from Middle East conflict and accounting reclassifications: ~$3 million impact to International Solutions direct margins from allocating rig reactivation CapEx to OpEx
  • Middle East conflict cost estimate: ~$3.5 million impact on direct margins in the quarter (crisis management, supply chain inflation, slower rig starts, Iraq suspension)
  • Third-quarter assumed Middle East cost impact: ~$6 million at midpoint guidance if Strait of Hormuz remains effectively closed (inclusive of Iraq/Bahrain suspensions)
  • North America Solutions direct margin: $215 million, near midpoint of guidance; total direct margin taper to $17,600/day; day rates stable, overhead absorption reduced as rig count stepped down

AI IconCapital Funding

  • Term loan repayment: fully repaid remaining $400 million term loan ahead of schedule (per guidance update)
  • Planned next deleveraging focus: $350 million bond due end of 2027 (repayment anticipated ahead of schedule)
  • Cash & short-term investments: ~$199 million at end of Q2’26
  • Total liquidity including revolver availability: ~$1.15 billion
  • CapEx: $63 million in Q2 (below anticipated spending); FY gross capital budget raised/realigned to high end ~$270 million to $310 million
  • FCF: negative in quarter due to rare timing lag (receivables collected vs payables disbursed); excluding working capital, FCF was $74 million

AI IconStrategy & Ops

  • International reactivation execution under supply chain constraints: used in-house engineering and aftermarket capabilities to reactivate Saudi rigs using in-country equipment, avoiding customer delays
  • Accounting-driven margin volatility: rig reactivation capital expenditures in the Middle East classified as OpEx, pressuring direct margins
  • Enterprise optimization: reduced SG&A by >$50 million versus premerger stand-alone run rates; continued harmonization of systems/processes across Western and Eastern Hemisphere
  • Portfolio optimization milestone: sale of Utica Square; sale proceeds exceeded $100 million divestment target
  • Operational footprint management: 1 rig suspension in Iraq during quarter; notification of suspension of 2 rigs in Bahrain for up to 90 days

AI IconMarket Outlook

  • North America Solutions (NAS) Q3’26 direct margin guidance: $230 million to $240 million with anticipated rig count of 137 to 143
  • Full-year NAS rig count range raised: 138 to 144 rigs (previously implied lower range); expects positive inflection in margin rates
  • International Solutions Q3’26 and full-year rig count guidance: 58 to 68 rigs
  • International Solutions direct margin guidance (Q3): $12 million to $32 million; midpoint assumes ~$6 million direct margin impact if Strait of Hormuz remains effectively closed
  • Offshore Solutions guidance: average 30 to 35 management contracts and operating rigs; direct margin rate Q3 $24 million to $28 million; full-year direct margin guidance reaffirmed at $100 million to $115 million
  • FY’26 cash taxes guidance increased (due to Utica Square sale): $125 million to $150 million
  • FlexRobotics deployment timing: first 3–4 systems operational this calendar year (2026) as part of 4-rig phased deployment

AI IconRisks & Headwinds

  • Middle East conflict remains a major risk to International direct margins and rig uptime: discrete Q2 impacts expected to be followed by continued cost inflation and potential outage impacts
  • Strait of Hormuz closure assumption drives sensitivity: ~$6 million midpoint third-quarter direct margin impact if effectively closed for duration
  • Rig suspensions: 1 rig suspended in Iraq; up to 90-day suspension notification for 2 rigs in Bahrain
  • Supply chain constraints in the Middle East continue to constrain timely drilling starts and increase operating costs (crisis response, supply chain cost inflation)
  • Capital/timing risk: free cash flow volatility from working-capital timing lags and higher-than-expected cash taxes

Q&A: Analyst Interest

  • NAS recovery path, rig count expectations (mid-140s) and margin progression: Management framed Q2 as the trough, tied rig pickup to private independent operator extensions plus emerging public-company rhetoric, and emphasized tight DUC/location scarcity plus super-spec utilization. They linked margin improvement to rising activity and durable customer pull.
  • Lower 48 structural fundamentals: Management cited needing ~15,000 wells/year to hold Lower 48 production flat, noted 70% of production from wells drilled within last 2–3 years, and argued accelerating decline/rock degradation increases drilling intensity. They also highlighted super-spec reactivation market where idle rigs can return quickly (utilization >80%).
  • Operational execution advantage for reactivations: Management and Lennox highlighted H&P’s scale (~30% Lower 48 fleet; >30% industry share), 20-plus super-spec rigs available for maintenance-CapEx reactivation (~$1M–$4M), and speed metrics from a Delaware Basin study (4.6 days ahead by first well; 5.3 by 10th well versus competitors).

Sentiment: POSITIVE

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