Offshore Oil and Gas Operator Risk Profile India 2026: Deepwater Drilling, Control of Well and Operators Extra Expense

Indian offshore exploration and production (E&P) is moving from mature shallow-water fields into a deepwater and ultra-deepwater phase, and the insurance profile is changing with it. Under the Open Acreage Licensing Policy (OALP) Round-X, the government offered 25 blocks spanning roughly 190,000 sq km, with nearly two-thirds of the acreage in ultra-deepwater and a cluster of blocks in the Andaman basin covering about 47,000 sq km. Bidding was extended into 2026 as operators assessed the frontier geology and the drilling cost of water depths beyond 2,500 metres.

The technical case firmed up in September 2025 when Oil India confirmed a natural gas discovery at its Sri Vijayapuram well in the Andaman offshore area, with gas testing at roughly 87 percent methane. ONGC, meanwhile, has signalled an intent to hold acreage approaching 500,000 sq km by March 2026, and the proven Krishna-Godavari (KG) basin deepwater blocks continue to anchor east-coast production. The Andaman campaign has been described publicly as a multi-billion-dollar frontier gamble, which is exactly the kind of exposure that reshapes an operator's risk register.

This matters for insurance because offshore upstream is a distinct energy risk, not a variant of the downstream refinery or coastal tank-farm profile. The dominant loss scenarios are a well blowout during drilling or workover, physical loss of a mobile offshore drilling unit or fixed platform, and a seepage and pollution event radiating from the wellhead. The core package is built around Operators Extra Expense (OEE) and Control of Well cover, sitting alongside offshore physical damage and third-party liability. For a broker placing an Indian upstream account in 2026, the move into deepwater changes the sum insured logic, the well-control cost assumptions, and the reinsurance capacity the placement draws on. The sections that follow set out each layer of that programme.

The heart of an upstream operator's insurance is the Operators Extra Expense (OEE) policy, most often written on the London market EED 8/86 wording (Energy Exploration and Development). The policy is organised into three coverage sections that track the sequence of a well-control incident.

Section A, Control of Well. This responds to the cost of regaining control of a well that has blown out or become uncontrollable, whether the flow is above the surface or an underground blowout into another formation. It funds the well-control specialists, relief-well drilling, capping stacks, firefighting, and pumping and mud costs incurred to bring the well back under control and "make it safe".

Section B, Redrilling and Extra Expense. Once control is regained, Section B funds the cost to restore or redrill the well to the depth and condition it was in before the event. For a deepwater well where a single hole can cost tens of millions of dollars, the redrill exposure alone can dwarf the physical asset value.

Section C, Seepage, Pollution, Contamination and Cleanup. This picks up the operator's cost to control and clean up seepage and pollution emanating from a well, plus evacuation expenses, subject to the sub-limits and occurrence terms in the wording.

Limits are usually written on an each-and-every-occurrence basis with a combined single limit across the sections and a self-insured retention. For Indian offshore operators, OEE limits commonly run from tens of millions of US dollars for shallow-water development wells to several hundred million dollars for high-pressure high-temperature (HPHT) deepwater exploration. The Macondo blowout in the Gulf of Mexico in 2010 remains the reference point that recalibrated deepwater OEE and pollution limits globally, and it shapes how underwriters price the Andaman and KG deepwater campaigns.

The physical asset side of an offshore programme is written separately from OEE and is where marine and energy underwriting meet. The exposures fall into three groups.

Mobile Offshore Drilling Units (MODUs). Jack-up rigs, semi-submersibles and drillships are high-value floating assets, often owned by a drilling contractor and hired to the operator under a day-rate contract. They are insured on energy physical damage or marine hull-insurance wordings covering the unit against perils of the sea, collision, grounding, fire, and total loss. A deepwater drillship can carry a hull value in the hundreds of millions of dollars, and towage, positioning and well-control equipment on board add to the exposure. The knock-for-knock liability allocation between operator and drilling contractor, set in the drilling contract, determines whose policy responds and is a central review point for the broker.

Fixed platforms and processing structures. Wellhead platforms, process platforms and the jackets that support them are insured against physical damage on offshore construction or operational property wordings, frequently the WELCAR 2001 offshore construction all-risks form during the build and installation phase. The Bombay High North platform fire in July 2005, which destroyed an ONGC process complex and killed 22 people, remains the defining Indian offshore property loss and a standing reminder of accumulation risk where multiple structures sit in a single field.

Subsea and pipeline infrastructure. Subsea trees, manifolds, flowlines, risers and export pipelines are insured for physical damage and for the cost of subsea intervention to locate and repair damage, which can be a large multiple of the component value at deepwater depths.

Business interruption and loss of production income (LOPI) sit on top of the property programme, funding lost revenue during the shut-in and repair period. For a producing deepwater field, the LOPI indemnity period, typically 12 to 24 months, and the daily production value drive a sum insured that can exceed the physical asset value several times over. Underwriters scrutinise the redundancy of subsea systems and the availability of intervention vessels when setting LOPI terms.

Liability is the exposure that turns an offshore incident into a balance-sheet event, and it is governed by a mix of policy wording and Indian statute. An operator faces claims for bodily injury to personnel, damage to third-party property and vessels, and, above all, pollution of the marine environment.

The pollution response comes from two directions. Section C of the OEE policy funds seepage, pollution, contamination and cleanup arising from the insured well. Beyond that, an operator carries a separate third-party-liability or Energy package casualty section, and often a dedicated Offshore Pollution Liability layer, to respond to third-party claims and to statutory cleanup demands that exceed the OEE sub-limit. The distinction between first-party cleanup cost and third-party pollution liability is a frequent source of coverage dispute, so the interlock between the two wordings has to be read together.

On the regulatory side, an offshore blowout in Indian waters engages the National Oil Spill Disaster Contingency Plan (NOS-DCP) coordinated by the Indian Coast Guard, the licence conditions set by the Directorate General of Hydrocarbons (DGH) and the Petroleum and Natural Gas Rules, and environmental obligations under the Environment (Protection) Act 1986 and the applicable Coastal Regulation Zone framework. India is a party to the international marine pollution conventions, and an operator's contractual chain with drilling and vessel contractors passes further pollution obligations up and down the line.

Operators drilling in ecologically sensitive Andaman waters face heightened scrutiny of spill response capability, and reinsurers increasingly ask for a documented response plan and modelled worst-case discharge before deploying pollution capacity. Personnel liability, including cover aligned to workers-compensation obligations for offshore crew, rounds out the casualty picture.

The move into deepwater is not a linear extension of shallow-water risk; several exposures scale non-linearly with water depth and reservoir pressure, and underwriters price them accordingly.

Well-control cost escalation. In deep water a blowout may require a purpose-built relief well, a capping stack mobilised from an international stockpile, and specialist vessels on extended standby. The time to regain control can run to weeks or months, and every element is more expensive at depth. The redrill cost under OEE Section B rises with the same multiplier. This is why deepwater exploration wells often carry OEE limits several times those of a shallow-water development well.

HPHT reservoir conditions. Several KG-basin and frontier prospects are high-pressure high-temperature, which raises the probability and severity of a kick or blowout and stresses the blowout preventer and well-control equipment. Underwriters load rates for HPHT wells and may attach specific warranties on equipment testing and casing design.

Andaman frontier factors. The Andaman basin combines great water depth, remoteness from support infrastructure, seismic activity, and weather windows that compress the drilling calendar. Remoteness lengthens the time to mobilise well-control resources, which feeds directly into the Control of Well and pollution scenarios, and the region's ecological sensitivity raises the potential liability quantum of any spill.

Contractual risk transfer. Deepwater drilling involves layered contracts among the operator, the rig contractor, the well-services companies and vessel owners. The knock-for-knock indemnity structure allocates who bears rig damage, well-control cost and pollution, and any gap or ambiguity in those indemnities becomes an uninsured exposure. Reviewing the drilling contract against the insurance wordings is as important as the placement itself.

For the KG basin, where deepwater production is established, the profile blends producing-asset property and business interruption exposure with ongoing infill drilling risk. For the Andaman, the near-term profile is dominated by exploration drilling, so OEE and pollution capacity carry more weight than producing-asset LOPI. A broker sizing an Indian upstream programme in 2026 has to profile each campaign on its own drilling and reservoir facts rather than applying a single template.

Indian offshore upstream risks are large, specialised and heavily reinsurance-driven. Under the IRDAI (Reinsurance) Regulations 2018, an Indian cedant places these risks through the domestic market with GIC Re as the national reinsurer holding first right of refusal, and the balance flows to the international energy market in London, Continental Europe and the Lloyd's syndicates. The energy sector mutual Oil Insurance Limited (OIL) also participates for the national oil companies, providing a layer of member-based capacity.

A full upstream programme for an Indian operator typically stacks the following covers.

1. Operators Extra Expense and Control of Well on EED 8/86, with a combined single limit and each-and-every-occurrence terms.
2. Offshore physical damage for MODUs (energy or marine hull) and platforms and subsea assets (operational property or WELCAR 2001 during construction).
3. Loss of production income and business interruption with a defined indemnity period.
4. Third-party and offshore pollution liability, interlocking with OEE Section C.
5. Construction and installation cover for new platforms, pipelines and tie-backs, often on WELCAR.
6. Personnel and marine liability for offshore crew and support vessels.

Product filing follows the IRDAI Use and File regime for the Indian-issued sections, while the specialty wordings are drawn from established London market forms.

Pricing in 2026 sits in a firm but stable energy market. Deepwater exploration OEE carries materially higher rates on line than shallow-water development because of the well-control and redrill cost basis, and HPHT and frontier Andaman wells attract further loading. Physical damage rates track the international MODU and platform market, which has firmed after several years of offshore losses. Precise rates move with each renewal and each well design, so the practical point is that the capacity and terms achieved depend on submission quality: the drilling programme, the well-control equipment specification, the contractor indemnity chain, and the modelled worst-case discharge for pollution capacity. Placements presented with weak engineering detail draw narrower capacity at higher cost.

For a broker, risk manager or underwriter working an Indian offshore account, the deepwater shift makes wording precision more valuable than headline limits. The same policy name can behave very differently depending on how a handful of clauses are drafted, and those differences decide claims.

The review points that repeat across upstream placements are consistent. The Control of Well trigger and the definition of when a well is "under control" govern where Section A stops and Section B begins. The redrill cost basis in Section B has to reflect deepwater drilling economics, not a shallow-water benchmark. The seepage and pollution sub-limit in Section C, read against the separate third-party pollution layer, determines whether a large spill is fully funded. The knock-for-knock indemnities in the drilling and services contracts have to align with the insurance wordings so that no exposure falls between the two. And the LOPI indemnity period and daily-value basis have to match the real time to restore deepwater production. Each of these lives in the fine print of the wording, and each varies between insurers and between renewals.

This is where searchable policy-wording intelligence earns its place. Sarvada indexes insurer policy wordings so a broker can compare how different insurers draft the Control of Well trigger, the redrill basis, the pollution sub-limits and the offshore exclusions, side by side, in the language that appears on the slip. Instead of reconstructing each wording by hand at every renewal, a team can search across the market, spot where a clause is narrower than it looks, and build the upstream programme on evidence rather than memory. If you place or underwrite Indian offshore E&P risk, you can request access to see how the platform surfaces these differences across the wordings you work with.