Northern Drilling Ltd. Overview
Northern Ocean Ltd. is a single-asset, Bermuda-domiciled offshore drilling rig owner controlled by John Fredriksen's Hemen Holding. Its sole asset is Deepsea Mira, a sixth-generation Moss Maritime CS60 harsh-environment semi-submersible rated for 10,000 ft water depth and delivered in December 2018. It is operated and marketed by Odfjell Drilling under a management agreement. NOL was carved out of Northern Drilling in 2019 and survived a turbulent 2020–2022 marked by a Seadrill-related settlement, a terminated Wintershall Dea contract and multiple dilutive equity raises. It then rebuilt credibility in Namibia's frontier Orange Basin with TotalEnergies, Shell, Rhino Resources and BW Energy. In December 2025 it sold sister rig Deepsea Bollsta to Odfjell for USD 480 million, deleveraging from about USD 531 million of debt to USD 100 million. The investment case now depends on a single rig and on its Shell Trinidad & Tobago contract starting April 2027, with Hemen-affiliated funding as the liquidity backstop.
Company's own description. In its Q4 2025 and Q2 2026 interim reports, NOL describes itself as owning and operating one of the world's newest and most capable harsh-environment semi-submersibles, Deepsea Mira, suited to operations across all major offshore basins. It frames itself as well positioned for a tightening supply of high-end rigs. Stated near-term priorities are securing new contracts for Deepsea Mira, operational efficiency and cost control, and refinancing. Its corporate boilerplate (October 2026 releases) describes an international drilling contractor whose purpose is to own high-specification offshore drilling units designed for harsh environments.
What the company actually does. NOL earns revenue by contracting Deepsea Mira to oil and gas operators under day-rate drilling contracts. These contracts typically run one to a few wells, or longer campaigns with options. Revenue streams under US GAAP are:
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Day-rate revenue. Fees per operating day, with lower or zero rates when operations are interrupted. FY2025 day-rate revenue was USD 199.1 million of USD 271.9 million contract revenue (Q4 2025 report, Note 3).
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Mobilization / contract-preparation revenue. Lump-sum or variable fees, deferred and amortized over the firm term (FY2025: USD 43.6 million amortized, including USD 38.2 million accelerated on the Bollsta sale).
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Demobilization revenue (FY2025: USD 7.5 million).
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Other / add-on services (FY2025: USD 21.6 million). Fuel sales and incremental services are reported gross.
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Reimbursable revenue. Pass-through of customer-requested purchases (FY2025: USD 7.4 million).
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Other income. Historically management fees charged to Northern Drilling (USD 1.0 million in FY2023).
Revenue model mix. This is essentially 100% service revenue (contract drilling). There is no product, subscription or licensing revenue. A small government grant (Norwegian NOx fund, related to Mira's emissions-reducing systems) is amortized at about USD 0.1 million per year.
Value chain position. NOL sits in the offshore drilling contractor tier of the upstream oil and gas value chain. Upstream of NOL are shipyards (Hyundai built both semi-submersibles), equipment OEMs (e.g., Kinetic Pressure Control, with which NOL signed an LOI for blowout-stopper technology) and rig managers (Odfjell Drilling). Downstream are exploration and production operators: supermajors (Shell, TotalEnergies, Equinor), independents (Rhino Resources, BW Energy, Impact Oil & Gas) and national or emerging operators (Springfield Group in Ghana). NOL is an asset-light owner in a structurally asset-heavy industry. It owns the capital asset but outsources operational execution.
Customer types and end-markets. Customers are exploration and production companies drilling exploration, appraisal and development wells in deep and ultra-deep water and harsh environments. End-markets served since 2019 include the Norwegian Continental Shelf (Lundin, Wintershall Dea, Equinor), Namibia's Orange Basin (Shell, TotalEnergies, Rhino, BW Energy, Impact via TotalEnergies), Republic of Congo (TotalEnergies), Ghana (Springfield) and, from April 2027, Trinidad & Tobago and the wider Caribbean (Shell).
Independent characterization. NOL is best understood as a levered, single-rig option on the harsh-environment / ultra-deepwater floater cycle, governed by a controlling shareholder who is also its primary lender (Sterna Finance, a Hemen affiliate). Its economics are binary. When Mira works, quarterly revenue runs at about USD 30–34 million (Q2 2026: USD 34.1 million total operating revenue at 98.6% economic utilization). When Mira idles, the company burns cash and relies on Hemen-affiliated funding. The December 2025 Bollsta sale crystallized value at roughly the original acquisition cost, removed most bank debt, and also halved earning capacity and concentrated risk.
Strategy
Stated strategy (Q4 2025 CEO letter and 2025–2026 interim reports), paraphrased themes:
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Maximize value of Deepsea Mira through disciplined contracting. Evaluate each opportunity on commercial terms and timing, committing the rig only on terms reflecting its demonstrated performance and the evolving market structure.
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Capital preservation, then capital return. Preserve capital until contract visibility and runway are established, then begin returning capital to shareholders. The Bollsta sale was explicitly framed as enabling capital returns.
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Opportunistic refinancing. Keep the Sterna facility until backlog supports better refinancing terms. This was overtaken in October 2026 by an amend-and-extend with Sterna.
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Market thesis. Management expects more disciplined pricing in ultra-deepwater after the Valaris/Transocean merger (Q4 2025 CEO letter) and sees a building pipeline of term work for 2027 starts.
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Operational excellence and local content. Emphasis on safety, efficiency and Namibian local content in partnership with Odfjell.
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Asset upgrades. Mira's drilling-control upgrade (2026) and the K-BOS LOI (Oct 2024).
Strategic initiatives in the last 24 months (Oct 2024 – Oct 2026)
Medium-term targets / guidance. NOL provides no quantitative medium-term financial targets (no revenue, EBITDA, leverage or dividend targets). Qualitative guidance: Mira idle into Q1 2027; operations expected to commence April 2027; capital returns once runway and visibility are secured, with no amount or timing given.
ESG commitments. No formal emissions targets disclosed. Existing hybrid battery systems and NOx-reduction equipment are cited.
Products & Services
NOL offers a single service line (integrated contract drilling services) delivered through its rig fleet. Each rig is catalogued below.
Deepsea Mira (ex-West Mira), the current sole asset
| Attribute | Detail |
|---|---|
| Type | 6th-generation harsh-environment / ultra-deepwater semi-submersible drilling rig |
| Design | Moss Maritime CS60 |
| Builder | Hyundai (originally ordered by Seadrill in 2012; Seadrill cancelled for late delivery; acquired by the Fredriksen/NODL vehicle in 2017) |
| Delivery to company | December 2018 |
| Water depth capability | Up to 10,000 ft |
| Environmental features | Hybrid battery system lowering fuel consumption, NOx and CO2 (2022 annual report); NOx-reduction systems qualified for a Norwegian government grant |
| Recent upgrades | Drilling control system upgrade completed in a 30-day window at Walvis Bay after the July 2026 Shell well. It brings Mira to the same control capability as Bollsta, a capability management says is increasingly required in long-term major-operator tenders (Q2 2026 report). BOP certificate renewal completed in 2025 (Q4 2025 report, Note 17) |
| Planned technology | LOI (Oct 2024) with Kinetic Pressure Control to outfit the rigs with the Kinetic Blowout Stopper (K-BOS) |
| Operator / manager | Odfjell Drilling (marketing and management since 2022) |
| Contract history | Wintershall Dea, NCS (terminated May 2021) → warm-stacked near Bergen 2021–2023 → TotalEnergies Namibia/Congo (Jun 2023–2025, including Impact Oil & Gas's Marula-1X spud Feb 2025) → BW Energy, Namibia (to 23 Nov 2025) → Rhino Resources, Namibia (Volans-1X and a well test, to 31 Jan 2026) → Shell, Namibia (4 Apr–2 Jul 2026, about USD 31 million revenue) → idle at Walvis Bay → Shell, Trinidad & Tobago / Caribbean (expected start Apr 2027; 150 days firm about USD 70 million; 1-year option takes the total to about USD 226 million) |
| Pricing model | Day rate plus mobilization/demobilization lump sums plus reimbursables. Specific Mira day rates not disclosed. Implied Q2 2026: about USD 32.3 million day-rate revenue over 91 days ≈ USD 355,000/day gross (derived, not company-stated) |
| Book value | USD 431.6 million (30 Jun 2026) |
Deepsea Bollsta (ex-West Bollsta / Bollsta Dolphin), divested 15 Dec 2025
| Attribute | Detail |
|---|---|
| Type / design | 6th-generation harsh-environment semi-submersible, Moss Maritime CS60 (sister rig to Mira) |
| Origin | Originally ordered by Fred. Olsen Energy as Bollsta Dolphin and cancelled; NODL exercised its USD 400 million option (late 2017) |
| Delivery | June 2019 |
| Contract history | Lundin NCS (Oct 2020–Q1 2022, bareboat via Seadrill) → hot-stacked Bergen → Shell Namibia (Dec 2022–mid 2024) → 5-year special periodic survey in Namibia (Q3 2024) → Springfield Group Ghana Afina-1x well test (Q4 2024, USD 440,000/day clean rate) → one well for a major operator in Namibia → Norway bridging contract (2025) → Equinor long-term NCS contract (from late 2025; fixed to end-2027 excluding options) |
| Disposal | Sold to an Odfjell Drilling subsidiary for USD 480 million cash, effective 15 Dec 2025 |
Integrated service elements (per 2022 audited accounts, revenue recognition note)
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Provision of the drilling rig, crew and supplies (crews via Odfjell)
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Rig mobilization and demobilization to and from the drill site
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Rig preparation and contract-specific modifications
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Add-on services and fuel sales at contract commencement
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Reimbursable procurement of supplies, equipment and personnel at customer request
Northern Drilling legacy "portfolio" (non-operating, historical): West Aquila and West Libra (7th-gen DSME drillships, resale contracts at USD 296 million each, terminated 2021); West Cobalt (DSME drillship, USD 350 million resale, terminated Oct 2019). None was ever delivered to NODL. Hanwha later sold West Aquila to a Transocean-linked JV for about USD 200 million (Offshore Energy).
Financial Narrative
Sources: FY2021 and FY2022 from NOL Consolidated Financial Statements 2022 (audited); FY2023 from the Q4 2023 interim report (unaudited, with 2022 comparatives); FY2024 and FY2025 from the Q4 2025 interim report (unaudited, with 2024 comparatives). US GAAP, USD millions. Derived figures are analyst calculations.
Margins and growth (%)
The CAGR is flattered by a depressed 2021–2022 base, when both rigs were largely idle.
Balance sheet
Interim update (30 June 2026, Q2 2026 report): total assets USD 496.9 million; Mira carrying value USD 431.6 million; cash USD 19.7 million; related-party debt USD 132.8 million (USD 107.8 million term loan including USD 7.8 million capitalized PIK, plus USD 25.0 million fully drawn receivables RCF); equity USD 318.7 million. By 28 August 2026 borrowings had fallen to USD 112.8 million as customer receipts repaid the RCF to USD 5.0 million.
Ratios
Blank net debt/EBITDA cells for FY2021–FY2022 are not meaningful because EBITDA was negative. FY2021 DSO shows 0 because receivables were nil at year end. A conventional cash conversion cycle is not meaningful for a rig owner (no inventory model), so DSO is shown instead.
Commentary: trends, inflections, drivers
2021–2022 trough. Both rigs were largely idle or under compromised contracts. Mira's Wintershall contract was terminated in May 2021, and Bollsta's Lundin work ended in Q1 2022. Revenue fell to USD 21.7 million in FY2022 with negative gross contribution. The 2021 net loss was cushioned by a USD 57.6 million non-cash Seadrill settlement gain. Without it, the continuing loss was USD 68.6 million.
2023 inflection. Simultaneous Shell (Bollsta) and TotalEnergies (Mira) contracts in Namibia lifted revenue tenfold to USD 236.9 million, and EBITDA turned positive (USD 19.3 million). Large reactivation and mobilization costs were deferred and amortized, depressing reported margins (FY2023 rig opex included USD 65.0 million of amortized deferred costs).
2024 peak operating year. Revenue reached USD 263.9 million and EBITDA USD 39.7 million (15.1% margin), despite Bollsta being off-contract through Q3 2024 for its 5-year special periodic survey. Interest expense of USD 56.3 million exceeded EBITDA, so the company still lost money, demonstrating that the 2019-vintage capital structure was unsustainable at mid-cycle day rates.
2025 transformation. Underlying operations were solid (Q4 2025 Mira economic utilization 99.1%, Bollsta 87.7%). However, the Bollsta sale triggered a USD 13.1 million impairment, a USD 59.3 million deferred-cost write-through, a USD 38.2 million deferred-revenue release and a USD 4.6 million management-agreement termination charge. The net loss widened to USD 102.7 million. Balance-sheet repair was dramatic: total debt fell from USD 530.8 million to USD 100.0 million and net debt/EBITDA from 12.3x to 2.8x.
2026 single-rig reality. H1 2026 revenue was USD 47.4 million (Q1 USD 13.3 million, 35 operating days; Q2 USD 34.1 million, 91 days) with a net loss of USD 25.6 million. Q2 alone came close to breakeven (net loss USD 2.5 million). This shows Mira can roughly cover interest and depreciation when fully employed at current rates, but not when idle. Idle time from July 2026 to April 2027 forced the October 2026 recapitalization.
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Revenue by Segment and Segment Margins & Growth (%)
| Metric | FY2023 | FY2024 | FY2025 |
|---|---|---|---|
Segment total operating revenues (USD Mn) | 236.9 | 263.9 | 279.4 |
Contract revenue (USD Mn) | 215.3 | 252.6 | 271.9 |
Day-rate revenue (USD Mn) | 166.5 | 0 | 199.1 |
Segment operating income (USD Mn) | -23.6 | -10.2 | -45.9 |
Segment pre-tax income (USD Mn) | -68.1 | -63.3 | -100.5 |
Operating margin (%) | -10.0 | -3.9 | -16.4 |
Revenue YoY growth (%) | 993.7 | 11.4 | 5.9 |
Contribution to total revenue (%) | 100 | 100 | 100 |
Rigs owned at year end (count) | 2 | 2 | 1 |
Components
| Component | FY2023 | FY2025 |
|---|---|---|
Day-rate revenue (USD Mn) | 166.5 | 199.1 |
Amortization of deferred (mobilization) revenue (USD Mn) | 30.4 | 43.6 |
Demobilization revenue (USD Mn) | 8.5 | 7.5 |
Other / add-on (USD Mn) | 9.9 | 21.6 |
Total contract revenue (USD Mn) | 215.3 | 271.9 |
Income Statement and Per-Share Data
| Metric | FY2021 | FY2022 | FY2023 | FY2024 | FY2025 |
|---|---|---|---|---|---|
Total operating revenues (USD Mn) | 67.8 | 21.7 | 236.9 | 263.9 | 279.4 |
Contract revenue (USD Mn) | 56.6 | 20.4 | 215.3 | 252.6 | 271.9 |
Reimbursable revenue (USD Mn) | 9.7 | 0 | 19.9 | 10.9 | 7.4 |
Rig operating expenses (USD Mn) | 52.0 | 37.4 | 191.1 | 206.3 | 241.2 |
Reimbursable expenses (USD Mn) | 7.6 | 0 | 19.0 | 10.8 | 7.9 |
Gross contribution: revenue less rig opex and reimbursables (USD Mn) | 8.2 | -15.8 | 26.8 | 46.7 | 30.3 |
Depreciation (USD Mn) | 42.7 | 40.2 | 42.9 | 49.9 | 55.1 |
Impairment (USD Mn) | 0 | 0 | 0 | 0 | 13.1 |
Provision for doubtful debts (USD Mn) | 5.4 | 0.4 | 0 | 0 | 0 |
Administrative expenses (USD Mn) | 10.1 | 7.6 | 7.5 | 7.0 | 7.9 |
Operating income / EBIT (USD Mn) | -50.0 | -64.0 | -23.6 | -10.2 | -45.9 |
EBITDA (EBIT + D&A + impairment) (USD Mn) | -7.4 | -23.8 | 19.3 | 39.7 | 22.4 |
Interest expense (USD Mn) | 19.6 | 27.9 | 46.0 | 56.3 | 56.3 |
Pre-tax income, continuing ops (USD Mn) | -71.7 | -92.5 | -68.1 | -63.3 | -100.5 |
Tax (charge) / credit (USD Mn) | 3.1 | -0.4 | -2.8 | -2.4 | -2.1 |
Related-party settlement gain, net (USD Mn) | 57.6 | 0 | 0 | 0 | 0 |
Net income (USD Mn) | -11.0 | -92.9 | -70.9 | -65.7 | -102.7 |
EPS basic and diluted (USD) | -0.17 | -0.80 | -0.39 | -0.32 | -0.34 |
EPS from continuing ops (USD) | -1.07 | -0.80 | -0.39 | -0.32 | -0.34 |
Dividends per share (USD) | 0 | 0 | 0 | 0 | 0 |
Weighted average shares (M) | 63.8 | 115.5 | 182.5 | 238.2 | 303.2 |
Margin Analysis (%)
| Metric | FY2021 | FY2022 | FY2023 | FY2024 | FY2025 |
|---|---|---|---|---|---|
Gross contribution margin (%) | 12.2 | -72.8 | 11.3 | 17.7 | 10.8 |
Operating margin (%) | -73.8 | -295.3 | -10.0 | -3.9 | -16.4 |
EBITDA margin (%) | -10.8 | -109.6 | 8.1 | 15.1 | 8.0 |
Net margin (%) | -16.3 | -428.8 | -29.9 | -24.9 | -36.7 |
Revenue growth YoY (%) | 0 | -68.0 | 993.7 | 11.4 | 5.9 |
Balance Sheet and Share Count (M)
| Metric | FY2021 | FY2022 | FY2023 | FY2024 | FY2025 |
|---|---|---|---|---|---|
Total assets (USD Mn) | 977.6 | 1,053.8 | 1,055.8 | 1,031.6 | 507.0 |
Drilling units, net (USD Mn) | 953.8 | 917.5 | 923.6 | 929.0 | 439.8 |
Cash and cash equivalents (USD Mn) | 5.5 | 67.5 | 54.4 | 42.8 | 37.5 |
Restricted cash (USD Mn) | 10.2 | 5.4 | 0.1 | 0.1 | 0.2 |
Short-term debt incl. related party (USD Mn) | 10.0 | 20.0 | 83.7 | 15.0 | 100.0 |
Long-term debt incl. related party (USD Mn) | 459.5 | 461.2 | 457.9 | 515.8 | 0 |
Of which bank debt (USD Mn) | 399.5 | 389.4 | 389.7 | 299.0 | 0 |
Of which related-party (Sterna) debt (USD Mn) | 70.0 | 91.8 | 151.9 | 231.8 | 100.0 |
Total debt (USD Mn) | 469.5 | 481.2 | 541.7 | 530.8 | 100.0 |
Net debt: total debt less cash and restricted cash (USD Mn) | 453.9 | 408.3 | 487.2 | 487.9 | 62.3 |
Total equity (USD Mn) | 495.6 | 506.8 | 436.9 | 446.2 | 345.1 |
Goodwill and intangibles (USD Mn) | 0 | 0 | 0 | 0 | 0 |
Working capital: current assets less current liabilities (USD Mn) | 4.3 | 55.4 | -36.0 | 35.5 | -92.3 |
Shares outstanding at year end (M) | 63.8 | 181.6 | 182.7 | 303.2 | 303.2 |
Cash Flow
| Metric | FY2021 | FY2022 | FY2023 | FY2024 | FY2025 |
|---|---|---|---|---|---|
Operating cash flow (USD Mn) | -21.8 | -52.8 | -30.6 | -19.4 | 4.4 |
Capex: drilling units and fixtures (USD Mn) | 0.2 | 4.7 | 49.0 | 55.4 | 57.8 |
Free cash flow (USD Mn) | -22.0 | -57.5 | -79.6 | -74.8 | -53.4 |
Net proceeds from share issuance (USD Mn) | 0 | 103.9 | 1.0 | 59.6 | 0 |
Related-party debt drawn (USD Mn) | 0 | 21.8 | 60.2 | 94.9 | 16.9 |
Debt repaid: bank and related party (USD Mn) | 0 | 10.0 | 0 | 90.0 | 448.7 |
Proceeds from asset sale (USD Mn) | 0 | 0 | 0 | 0 | 480.0 |
Dividends paid (USD Mn) | 0 | 0 | 0 | 0 | 0 |
Share buybacks (USD Mn) | 0 | 0 | 0 | 0 | 0 |
Returns & Leverage Ratios (%) and Financial Ratios (x)
| Ratio | FY2021 | FY2022 | FY2023 | FY2024 | FY2025 |
|---|---|---|---|---|---|
ROE on year-end equity (%) | -2.2 | -18.3 | -16.2 | -14.7 | -29.8 |
ROA on year-end assets (%) | -1.1 | -8.8 | -6.7 | -6.4 | -20.2 |
ROIC: EBIT ÷ (equity + net debt) (%) | -5.3 | -7.0 | -2.6 | -1.1 | -11.3 |
Current ratio (x) | 1.22 | 1.70 | 0.84 | 1.53 | 0.42 |
Debt / equity (x) | 0.95 | 0.95 | 1.24 | 1.19 | 0.29 |
Net debt / EBITDA (x) | — | — | 25.2 | 12.3 | 2.8 |
EBIT interest coverage (x) | -2.5 | -2.3 | -0.5 | -0.2 | -0.8 |
EBITDA interest coverage (x) | -0.4 | -0.9 | 0.4 | 0.7 | 0.4 |
Asset turnover on year-end assets (x) | 0.07 | 0.02 | 0.22 | 0.26 | 0.55 |
DSO: receivables + unbilled (days) | 0 | 322.9 | 73.8 | 76.0 | 32.7 |
Deepsea Mira by Period
| Period | Deepsea Mira | Deepsea Bollsta |
|---|---|---|
| 2020 | Norway (NCS) – Wintershall Dea | Norway (NCS) – Lundin, from Oct 2020 |
| 2021 | Norway – contract terminated May 2021; stacked near Bergen | Norway – Lundin |
| 2022 | Warm-stacked, Hanøytangen near Bergen | Norway – Lundin to Q1; hot-stacked Bergen; mobilized to Namibia; Shell from 10 Dec |
| 2023 | Namibia – TotalEnergies from Jun 2023 | Namibia – Shell |
| 2024 | Namibia, then Republic of Congo (Q3 2024) – TotalEnergies | Namibia – Shell to mid-2024; SPS in Namibia; Ghana – Springfield (Q4) |
| 2025 | Namibia – TotalEnergies / Impact; BW Energy; Rhino | Namibia (one well, major operator); Norway – bridging contract, then Equinor; sold 15 Dec 2025 |
| 2026 | Namibia – Rhino to 31 Jan; Shell 4 Apr–2 Jul; idle Walvis Bay | Divested |
2027 (contracted) | Trinidad & Tobago / Caribbean – Shell from Apr 2027 | Divested |
Share Price & Returns
| Reference point | Price (NOK) | Date / source |
|---|---|---|
NOL placement (Aug 2022) | 12.60 | 2022 annual report |
NOL placement (Dec 2022) and repair offering (Mar 2023) | 9.50 | 2022 annual report / Q4 2023 report |
NOL placement and Hemen offer (Jun–Aug 2024) | 7.00 | Jun–Jul 2024 releases |
Management option strike (Q3 2024 grant) | 12.00 | Q2 2026 report |
Hemen mandatory offer (Aug–Sep 2026) | 7.50 | Aug 2026 release |
NOL placement (Oct 2026) | 6.50 | Oct 2026 release |
Last observed quote (date unconfirmed) | about 7.46 | Snowball Analytics |
NODL placement (Nov 2017) | 64.00 | Bloomberg / gCaptain |
NODL mandatory offer (Mar 2022) | 17.00 | MFN release |
NODL mandatory offer (Dec 2023) | 0.125 | Dec 2023 release |
Valuation Snapshot
| Metric | Value | Basis |
|---|---|---|
Market cap, all shares at NOK 6.50 (NOK Mn) | about 2,657 | 408.76M shares × placement price |
Market cap, all shares at NOK 7.46 (NOK Mn) | about 3,049 | Unconfirmed last quote |
Approx. USD market cap at NOK 6.50 (USD Mn) | about 284 | Implied by placement (NOK 686M ≈ USD 71.7M → about 9.57 NOK/USD) |
Pro-forma net debt after placement (USD Mn) | about 65–80 | Analyst estimate: USD 112.8M debt (Aug 2026) less USD 11.7M PIK paid in shares, less net new cash; not company-stated |
EV / FY2025 sales (x) | about 1.2 | (USD 284M + about USD 70M) ÷ USD 279.4M; FY2025 included two rigs, so this flatters |
EV / FY2025 EBITDA (x) | about 15.8 | USD 354M ÷ USD 22.4M |
P/B (x) | about 0.7–0.8 | USD 284M ÷ (USD 318.7M June 2026 equity + about USD 71.7M new equity) |
EV / rig (USD Mn) | about 354 | Compare with Bollsta sale at USD 480M (Dec 2025) |
Capital Markets
| Metric | FY2021 | FY2022 | FY2023 | FY2024 | FY2025 |
|---|---|---|---|---|---|
Dividend per share (USD) | 0 | 0 | 0 | 0 | 0 |
Buybacks (USD Mn) | 0 | 0 | 0 | 0 | 0 |
Debt Facilities
| Facility | Lender | Amount | Terms | Maturity |
|---|---|---|---|---|
Term loan (amended Oct 2026) | Sterna Finance (Hemen affiliate) | USD 100 million | Floating; PIK option at a premium; secured on Deepsea Mira | Previous final maturity Dec 2026, extended 24 months (to about Dec 2028, analyst inference) |
Bridge facility | Sterna | USD 35 million | Any drawn amount repaid on placement completion | Short-term |
Factoring facility | Sterna | USD 15 million | Against approved client invoices | Ongoing |
Receivables RCF (Q2 2026) | Sterna | USD 25 million (USD 5.0M drawn at 28 Aug 2026) | Invoice-backed | Status post-refinancing not specified |
Bank term loans (USD 400M + USD 50M RCF, 2018–2019) | Bank syndicate | Repaid (USD 285M prepaid Dec 2025) | SOFR + 3.5% margin (2022 terms) | Cancelled |
Analyst Conclusions
Management guidance
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Deepsea Mira idle into Q1 2027 at Walvis Bay; Shell Trinidad & Tobago operations expected to start in April 2027 (150 days firm, about USD 70 million including mobilization and demobilization; option to about USD 226 million).
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The refinancing is expected to provide sufficient liquidity until the April 2027 start (Oct 2026 release).
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Opex reduced while idle; strategic decision gates in place for rig positioning; capital return contemplated once runway and visibility are secured (no quantification).
Consensus expectations
Thin coverage. MarketScreener's aggregated forecasts imply FY2026 revenue of about NOK 616 million (about USD 60–65 million) and FY2027 of about NOK 1,013 million, with net losses in both years.
Bull case
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Asset-value anchor. The identical sister rig sold for USD 480 million cash in Dec 2025. Against an indicative EV of about USD 350 million (at NOK 6.50) and a USD 432 million book value, Mira trades at a discount of roughly 25–30% to a recent arm's-length transaction.
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Contract visibility restored with upside. The Shell award delivers USD 70 million firm. If the 1-year option is exercised, the total rises to about USD 226 million, which would underpin roughly USD 150 million-plus of annualized revenue in 2027–2028 at Q2 2026 run-rates (about USD 34 million per quarter).
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Sponsor support and consolidating industry. Hemen injected about USD 60 million of fresh equity at NOK 6.50 and extended debt 24 months. Management expects disciplined pricing after large-contractor consolidation and a tight high-spec floater supply (13 available comparable units on NOL's 2023 analysis).
Bear case
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Single-rig binary risk. The company generated only USD 13.3 million revenue in Q1 2026 and burned cash in idle periods. Any slippage beyond April 2027, mobilization problems or an incident (cf. 2021) would require further Hemen-dependent funding.
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Structural unprofitability. Even in its best year (FY2024, two rigs, about USD 264 million revenue) NOL lost USD 65.7 million. FY2021–FY2025 cumulative FCF was about USD -287 million, and going-concern language recurs.
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Minority value leakage. Hemen now holds about 81–85%. Successive placements at declining prices, offers judged not fair by an independent expert, and the NODL precedent (NOK 0.125 exit, then delisting) point to elevated squeeze-out risk and low liquidity for minorities.
Key catalysts and monitorables (next 12 months)
| Catalyst | Expected timing | What to watch |
|---|---|---|
| Q3 2026 results | 26–27 Nov 2026 | Idle cost run-rate; cash after placement; refinancing terms detail |
| Subsequent (repair) offering | Q4 2026 | Prospectus approval; whether cancelled (if shares trade at or below NOK 6.50) |
| Listing prospectus for Hemen's separate-ISIN shares | Q4 2026 – Q1 2027 | Free-float changes |
| Additional backfill contracts for Mira | Before Apr 2027 | Any pre-Caribbean work; Namibia programs |
| Mobilization to Trinidad & Tobago | Q1 2027 | Cost and schedule; mobilization fee recognition |
| Shell contract commencement | Apr 2027 | On-time start; utilization |
| Shell option declaration | 2,027 | USD 156 million incremental value |
| Any Hemen squeeze-out / delisting proposal | Any time | Precedent from NODL (2023–2024) |
| Capital-return announcement | Post-backlog | Management commitment from Nov 2025 |
| FY2026 annual report and auditor opinion | Feb–Apr 2027 | Whether the going-concern emphasis persists |
Concluding analyst verdict
Northern Drilling Ltd., the entity on the input list, no longer exists as an investable security. It was a 2017 Fredriksen vehicle built to buy distressed rigs cheaply, and it exited public markets in April 2024 after losing its arbitration against Hanwha Ocean and being bought out by Hemen at NOK 0.125 per share. Its only surviving legacy is Northern Ocean Ltd., the 2019 spin-off holding the rigs NODL bought from Hyundai.
Northern Ocean today is a single-rig, controlled company. Its core asset is high quality: a 2018-delivered CS60 harsh-environment semi with near-perfect recent utilization and blue-chip repeat customers. The sister-rig sale at USD 480 million in December 2025 validates that quality. The sale also repaired a balance sheet that could not cover interest even in good years, cutting debt from about USD 531 million to USD 100 million. Yet the financial record is unambiguous. NOL lost money in every year from FY2021 to FY2025, consumed about USD 287 million of free cash flow, and has carried going-concern language almost continuously. The 2026 idle period from July to April 2027 showed that one rig cannot self-fund through contract gaps.
The October 2026 package removes near-term solvency risk. It comprises the Shell Trinidad & Tobago contract, a USD 71.7 million placement and a Sterna facility upsized and extended by 24 months, which gives the company a credible runway into April 2027 and a potential path to USD 226 million of revenue if Shell's option is exercised. Valuation looks undemanding against the Bollsta transaction marker.
For minority investors, however, the decisive variable is governance rather than rig economics. Hemen owns roughly four-fifths or more of the equity and is the sole lender. An independent expert found its 2026 offer unfair, and its treatment of NODL minorities is recent precedent. Verdict: asset value is real but is unlikely to accrue fully to minorities. Speculative, sponsor-dependent, high-risk; suitable only as a special-situation position with explicit squeeze-out risk tolerance.
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Executive Leadership Team
| Name | Title | Tenure | Prior roles | Education |
|---|---|---|---|---|
Arne Jacobsen | Chief Executive Officer | Since Aug 2024 (appointment announced 20 Aug 2024) | CEO of Orion (Hayfin Capital–Transocean JV); senior investment adviser for Hayfin's oil and gas portfolio; leadership roles at Songa Offshore and Ocean Rig (Brazil, South Korea, Norway) | — |
Jonas Ytreland | Chief Financial Officer | With NOL since Aug 2020; CFO since Jan 2022 | 10 years at Seadrill Management (last 8 as VP and Treasurer); Treasurer, Frontline Management; senior business adviser, SpareBank 1 SR-Bank | Degree in financial analysis, BI Norwegian Business School |
Eirik Sunde | Chief Commercial Officer | Appointment announced 12 Sep 2024; website states start Dec 2024 | Senior Marketing Manager, Transocean (Norwegian sector) | Master's in economics, University of Edinburgh |
“—” = not publicly disclosed.
Board of Directors
| Name | Role | Background | Independence (analyst view) |
|---|---|---|---|
Gary W. Casswell | Chairman | 45+ years in the industry; President and CEO, Northern Offshore Ltd (2010–mid-2017); VP Eastern Hemisphere Operations, Pride International; 20+ years at Santa Fe International; Director, Ensign Energy Services; IADC Exemplary Service Award 2007; BS Business Administration, Cal State Long Beach; US citizen, Houston | Independent of Hemen (no disclosed affiliation) |
Sven Børre Larsen | Director | CFO of TGS (2015–2019 and since Aug 2021; Head of Strategy and M&A in between); ex-CFO of Prosafe and Prosafe Production; MS Finance, Bodø Graduate School of Business | Independent |
Mikhael Botbol | Director | Senior adviser to Hayfin Capital (former senior partner and PM, Private Credit / special opportunities); founder of MB Asset Management; Brevan Howard; HBK; Goldman Sachs; Morgan Stanley; BA Mathematics (Paris VI), MSc UCLA, MBA INSEAD | Affiliated with Hayfin (historically about 21% holder after June 2024) |
Adrian Geelmuyden | Director | Investment Director, Seatankers Management (Fredriksen group); previously Solstad Offshore, Deep Sea Supply, RS Platou; director of Edda Wind, DOF Group, Archer; BSc NHH | Hemen-affiliated (signed Q2 2026 report) |
James Ayers | Director and Company Secretary (since Feb 2019) | CEO, Front Ocean Management; company secretary for Fredriksen-group Bermuda companies; LLM, LLB, LPC | Hemen-affiliated |
Lars Pedersen | Director | CTO, Frontline Management (8 years); MD, Flex LNG Fleet Management; prior BW Group, A.P. Moller–Maersk, Höegh; boards of Archer and Arundo Analytics | Fredriksen-group affiliated |
Major Shareholders
| Holder | Stake | Date / source |
|---|---|---|
Hemen Holding Ltd. (Fredriksen trusts) | 39.2% | 31 Dec 2022 (2022 accounts) |
Hemen Holding Ltd. | 39.0% | 31 Dec 2023 (Q4 2023 report) |
Hemen Holding Ltd. | 47.61% (144,373,315 shares) | 10 Jul 2024 (offer launch) |
Hemen Holding Ltd. | about 54.3% (164,548,905 shares) | 14 Aug 2024 (post NOK 7.00 offer) |
Hayfin Capital Management (funds) | 21.339% | Jul 2024 disclosure (post June 2024 placement) |
Hemen Holding Ltd. | Crossed 50% again (implying it had fallen below 50% after Aug 2024; a TRS agreement dated 15 May 2025 is referenced) | 9 Jul 2026 |
Hemen Holding Ltd. | about 78.3% (237,341,914 shares) | 4 Sep 2026 |
Hemen Holding Ltd. | about 83% (251,623,429 shares) | Post-offer, Sep 2026 |
Hemen Holding Ltd. + Sterna Finance (affiliate) | about 81.0% Hemen alone; about 85.2% including Sterna (derived: Hemen 330.9M and Sterna 17.3M of 408.8M shares) | Post Oct 2026 placement (analyst calculation from allocation announcement) |
Pelham Long/Short Small Cap Master Fund | 4.85% (crossed below 5%) | Undated historical disclosure (c. 2020–2021) |
Competitive Landscape
Key Competitors
| Competitor | Segment overlap | Relative positioning vs NOL |
|---|---|---|
Odfjell Drilling | Harsh-environment semis (Deepsea fleet); now owns Deepsea Bollsta; also NOL's operator | Direct competitor and partner; larger fleet; owns NOL's former sister rig |
Transocean (combined with Valaris per NOL's Q4 2025 CEO letter) | Harsh-environment semis and UDW drillships globally | Industry leader by fleet size; the consolidation is cited by NOL as supporting pricing discipline |
Seadrill | UDW drillships and harsh-environment units | Former manager of NOL's rigs; global UDW competitor |
Noble Corporation | UDW floaters (and harsh-environment jack-ups); consolidated Diamond Offshore's fleet | Large-scale competitor in floater tenders |
Stena Drilling | Harsh-environment semis and drillships (UK/Norway/Atlantic margins) | Direct competitor for harsh-environment semi work |
Saipem | Offshore drilling (semis, drillships) | Integrated contractor competitor in Africa and Norway |
COSL (China Oilfield Services) | Harsh-environment semis in the North Sea | Competitor on NCS and UKCS |
Dolphin Drilling | Harsh-environment semis (UK, West Africa) | Smaller competitor, overlapping West African and North Sea markets |
Vantage Drilling | UDW drillships in West Africa | Competitor for West African programs |
Shelf / other UDW owners (e.g., Constellation in Brazil) | Floaters | Peripheral competitors |
Competitor Detail
| Metric | Northern Ocean (FY2025) |
|---|---|
Revenue (USD Mn) | 279.4 |
Revenue growth YoY (%) | 5.9 |
EBITDA margin (%) | 8.0 |
R&D intensity (%) | 0 |
Rigs owned (count) | 1 |
Recent Developments
Upcoming: * Q3 2026 results expected 26–27 November 2026 (MarketScreener and MFN calendars); FY2026 report expected 26 February 2027.
