Exhibit 15.7

DEGOLYER AND MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

This is a digital representation of a DeGolyer and MacNaughton report.

This file is intended to be a manifestation of certain data in the subject report and as such are subject to the same conditions thereof. The
information and data contained in this file may be subject to misinterpretation; therefore, the signed and bound copy of this report should be considered the only authoritative source of such information.





LOGO



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DEGOLYER AND
MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

REPORT

as of

MARCH 31, 2016

on the

RESERVES and REVENUE

of

CERTAIN FIELDS

in

INDIA

owned by

CAIRN
INDIA LIMITED



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DEGOLYER AND MACNAUGHTON

TABLE of CONTENTS



|                                                                                                                   |  |      |    | 
|------------------------------------------------------------------------------------------------------------------ |  | ---- | -- | 
|                                                                                                                   |  | Page |   
|                                                                                                                   | 
|FOREWORD                                                                                                           |  |      | 1  | 
|                                                                                                                   | 
|Scope of Investigation                                                                                             |  |      | 1  | 
|Authority                                                                                                          |  |      | 3  | 
|Source of Information                                                                                              |  |      | 3  | 
|                                                                                                                   | 
|DEFINITION of RESERVES                                                                                             |  |      | 4  | 
|                                                                                                                   | 
|ESTIMATION of RESERVES                                                                                             |  |      | 10 | 
|                                                                                                                   | 
|VALUATION of RESERVES                                                                                              |  |      | 13 | 
|                                                                                                                   | 
|Discussion of Fiscal Terms                                                                                         |  |      | 14 | 
|RJ-ON-90/1 PSC (Rajasthan)                                                                                         |  |      | 14 | 
|CB/OS-2 PSC                                                                                                        |  |      | 15 | 
|PKGM-1 License Area (Ravva)                                                                                        |  |      | 15 | 
|                                                                                                                   | 
|SUMMARY and CONCLUSIONS                                                                                            |  |      | 17 | 
|                                                                                                                   | 
|TABLES                                                                                                             |  |      |    | 
|Table 1  Gross Proved Reserves                                                                                    |  |      |    | 
|Table 2  Net Proved Reserves                                                                                      |  |      |    | 
|Table 3  Reconciliation of Net Proved Reserves                                                                    |  |      |    | 
|Table 4  Standardized Measure of Discounted Future Net Cash Flows and Changes therein
relating to Proved Reserves |  |      |    | 



---

DEGOLYER AND
MACNAUGHTON

5001 SPRING VALLEY ROAD

SUITE 800 EAST

DALLAS, TEXAS 75244

REPORT

as of

MARCH 31, 2016

on the

RESERVES and REVENUE

of

CERTAIN FIELDS

in

INDIA

owned by

CAIRN
INDIA LIMITED

FOREWORD

Scope of
Investigation

This report presents estimates, as of March 31, 2016, of the extent and value of the proved oil, condensate,
and sales gas reserves of certain fields in India in which Cairn India Limited (Cairn) has represented that it owns an interest under the terms of various production sharing contracts (PSC) with the Government of India (GOI). For reporting purposes,
oil and condensate reserves have been estimated separately and are presented herein as a summed quantity.

Estimates of proved reserves
presented in this report have been prepared in compliance with the regulations promulgated by the United States Securities and Exchange Commission (SEC). These reserves definitions are discussed in detail in the Definition of Reserves section
of this report.

Reserves estimated in this report are expressed as gross and net reserves. Gross reserves are
defined as the total estimated petroleum to be produced from these properties after March 31, 2016. Net reserves are defined as that portion of the gross reserves attributable to the interests owned by Cairn after deducting all interests owned
by others.



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DEGOLYER AND MACNAUGHTON



Certain properties in which Cairn has represented that it owns an interest are subject
to the terms of various production sharing agreements. The terms of these agreements generally allow for working interest participants to be reimbursed for portions of capital costs and operating expenses and to share in the profits. The
reimbursements and profit proceeds are converted to a barrel of oil equivalent or standard cubic foot of gas equivalent by dividing by product prices to estimate the entitlement quantities. These entitlement quantities are equivalent in
principle to net reserves and are used to calculate an equivalent net share, termed an entitlement interest. In this report, Cairns net reserves or interest for certain properties subject to these agreements is the entitlement
based on Cairns working interest.

The fields evaluated herein are located in the CB/OS-2 PSC (three fields), the RJ-ON-90/1 PSC
(ten fields), and the PKGM-1 License Area (one field).

The CB-X, Gauri, and Lakshmi fields are located in the CB/OS-2 PSC, the
Aishwariya, Aishwariya Barmer Hill, Bhagyam, Mangala, Mangala Barmer Hill, N-E, N-I, Raagashwari (Shallow), Raagashwari Deep, and Saraswati fields are located in the RJ-ON-90/1 PSC, and the Ravva field is located in the PKGM-1 License Area.

The net entitlement interests for the properties evaluated in this report are calculated for each PSC and may change from year to year
depending on changes to the estimated costs projected for each field, the timing of production as well as price assumptions. Estimates of the entitlement interest for the total proved reserves for each PSC are as follows:



|                    |  |                            |       |  |                   |  |       | 
|------------------- |  | -------------------------- | ----- |  | ----------------- |  | ----- | 
|                    |  | Net EntitlementInterest    |      
|Area                |  | Oil andCondensate(percent) |       |  | SalesGas(percent) | 
|                    |  |                           
|CB/OS-2 PSC         |  |                            | 32.31 |  |                   |  | 34.46 | 
|RJ-ON-90/1 PSC      |  |                            | 48.64 |  |                   |  | 46.50 | 
|PKGM-1 License Area |  |                            | 14.09 |  |                   |  | 12.55 | 

This report also presents values that were estimated for proved reserves using prices and costs as of
the date the estimate was made. In this report, the prices and costs were held constant for the lives of the properties. An explanation of the price and cost assumptions is included in the Valuation of Reserves section of this report.



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DEGOLYER AND MACNAUGHTON



Values of the proved reserves in this report are expressed in terms
of estimated future net revenue and present worth. Future net revenue is calculated by deducting cash royalties, operating expenses, capital costs, production taxes, and host country income tax from the future gross revenue. Future gross revenue is
that revenue which will accrue to the evaluated interests from the production and sale of the estimated net reserves attributable to Cairn. Operating expenses include field operating expenses, workover costs, compression costs, and all other
direct costs specified by Cairn. Present worth is defined as the future net revenue discounted at a specified arbitrary discount rate compounded monthly over the expected period of realization. Present worth should not be construed as fair market
value because no consideration was given to additional factors that influence the prices at which properties are bought and sold. In this report, present worth values using a discount rate of 10 percent are reported.

Estimates of oil, condensate, and sales gas reserves and future net revenue should be regarded only as estimates that may change as further
production history and additional information become available. Not only are such reserves and revenue estimates based on that information which is currently available, but such estimates are also subject to the uncertainties inherent in the
application of judgmental factors in interpreting such information.

Authority

This report was authorized by Mr. Robert Merrill, Chief Reservoir Engineer, Cairn.

Source of Information

Information used in the preparation of this report was obtained from Cairn. In the preparation of this report we have relied,
without independent verification, upon information furnished by Cairn with respect to the properties to be evaluated, the production from such properties, current costs of operation and development, current prices for production, agreements relating
to current and future operations and sale of production, and various other information and data that were accepted as represented. A field examination of the properties was not considered necessary for the purposes of this report.



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DEGOLYER AND MACNAUGHTON



DEFINITION of RESERVES

Petroleum reserves included in this report are classified as proved. Only proved reserves have been evaluated for this report. Reserves
classifications used in this report are in accordance with the reserves definitions of Rules 4-10(a) (1)-(32) of Regulation S-X of the SEC. Reserves are judged to be economically producible in future years from known reservoirs under existing
economic and operating conditions and assuming continuation of current regulatory practices using conventional production methods and equipment. In the analyses of production-decline curves, reserves were estimated only to the limit of economic
rates of production under existing economic and operating conditions using prices and costs consistent with the effective date of this report, including consideration of changes in existing prices provided only by contractual arrangements
but not including escalations based upon future conditions. The petroleum reserves are classified as follows:

Proved oilandgasreserves Proved oil and gas reserves are those
quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible  from a given date forward, from known reservoirs, and under existing economic
conditions, operating methods, and government regulations  prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or
probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(i) The area of the reservoir considered as proved includes:

(A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that
can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as
seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.



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DEGOLYER AND MACNAUGHTON



(iii) Where direct observation from well penetrations has defined a highest known oil (HKO)
elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher
contact with reasonable certainty.

(iv) Reserves which can be produced economically through application of
improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:

(A) Successful testing by a pilot project in an area of the
reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or
other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (B)
The project has been approved for development by all necessary parties and entities, including governmental entities.

(v) Existing economic conditions include prices and costs at which economic producibility
from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined
as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future
conditions.

Probablereserves Probable reserves are those additional reserves that
are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.

(i) When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed
the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities
recovered will equal or exceed the proved plus probable reserves estimates.



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DEGOLYER AND MACNAUGHTON



(ii) Probable reserves may be assigned to areas of a reservoir
adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity
does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with
the proved reservoir.

(iii) Probable reserves estimates also include potential incremental quantities associated
with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves.

(iv) See also guidelines in paragraphs (iv) and (vi) of the definition of possible reserves.

Possible reserves Possible reserves are those additional reserves that are less certain to be recovered than
probable reserves.

(i) When deterministic methods are used, the total quantities ultimately recovered from a
project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately
recovered will equal or exceed the proved plus probable plus possible reserves estimates.

(ii) Possible reserves
may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this
will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a
defined project.



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DEGOLYER AND MACNAUGHTON



(iii) Possible reserves also include incremental quantities
associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves.

(iv) The proved plus probable and proved plus probable plus possible reserves estimates
must be based on reasonable alternative technical and commercial interpretations within the reservoir or subject project that are clearly documented, including comparisons to results in successful similar
projects.

(v) Possible reserves may be assigned where geoscience and engineering data
identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation
thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known
(proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the proved reservoir.

(vi) Pursuant to paragraph (iii) of the proved oil and gas
definition, where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves
should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of
the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations.



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DEGOLYER AND MACNAUGHTON



Developedoilandgasreserves Developed oil
and gas reserves are reserves of any category that can be expected to be recovered:

(i) Through existing wells with existing equipment and
operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

(ii) Through installed extraction equipment and infrastructure operational at the time
of the reserves estimate if the extraction is by means not involving a well.

Undevelopedoil andgasreserves Undeveloped oil
and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively
major expenditure is required for recompletion.

(i) Reserves
on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable
technology exists that establishes reasonable certainty of economic producibility at greater distances.

(ii) Undrilled
locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five
years, unless the specific circumstances justify a longer time.

(iii) Under no circumstances shall estimates for
undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an
analogous reservoir, as defined in [section 210.4-10 (a) Definitions], or by other evidence using reliable technology establishing reasonable certainty.



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DEGOLYER AND MACNAUGHTON



The extent to which probable and possible reserves ultimately may be reclassified as proved
reserves is dependent upon future drilling, testing, and well performance. The degree of risk to be applied in evaluating probable and possible reserves is influenced by economic and technological factors as well as the time element. No probable or
possible reserves have been evaluated for this report.



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DEGOLYER AND MACNAUGHTON



ESTIMATION of RESERVES

Estimates of reserves were prepared by the use of appropriate geologic, petroleum engineering, and evaluation principles and techniques that
are in accordance with practices generally recognized by the petroleum industry as presented in the publication of the Society of Petroleum Engineers entitled Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves
Information (Revision as of February 19, 2007). The method or combination of methods used in the analysis of each reservoir was tempered by experience with similar reservoirs, stage of development, quality and completeness of basic data,
and production history.

Based on the current stage of field development, production performance, the development plans provided by
Cairn, and the analyses of areas offsetting existing wells with test or production data, reserves were classified as proved.

When
applicable, the volumetric method was used to estimate the original oil in place (OOIP) and original gas in place (OGIP). Structure maps and isopach maps were used to estimate reservoir volumes. Electrical logs, radioactivity logs, core analyses,
and other available data were used to prepare these maps as well as to estimate representative values for porosity and water saturation. When adequate data were available and when circumstances justified, material-balance and other engineering
methods were used to estimate OOIP and OGIP.

For those reservoirs where the volumetric method was applied, estimates of ultimate
recovery were obtained after applying recovery factors to OOIP or OGIP. These recovery factors were based on consideration of the type of energy inherent in the reservoirs, analyses of the petroleum, the structural positions of the properties, and
the production histories. When applicable, material-balance and other engineering methods were used to estimate recovery factors. In such cases, an analysis of reservoir performance, including production rates, reservoir pressures, gas-oil ratio
(GOR) behavior, and water-oil ratio (WOR) behavior, was used in the estimation of reserves.

For depletion-type reservoirs or those whose
performance disclosed a reliable decline in producing-rate trends or other diagnostic characteristics, reserves were estimated by the application of appropriate decline curves or other performance relationships. In the analyses of
production-decline curves, reserves were estimated only to the limits of economic production based on existing economic conditions.



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DEGOLYER AND MACNAUGHTON



In certain cases, when the previously named methods could not be used, reserves were
estimated by analogy with similar wells or reservoirs for which more complete data were available.

Estimates of proved reserves
contained herein are based on forecasts that terminate at the economic limit, as defined in the Definition of Reserves section of this report, or at the end of the concession life, whichever occurs first.

Gas reserves estimated herein are expressed as sales gas at a temperature base of 60 degrees Fahrenheit and a pressure base of 14.7 pounds
per square inch absolute. Separator gas is defined as the total gas produced from the reservoir after deductions for normal field separation, but before fuel usage and flare losses. Sales gas is defined as the separator gas to be delivered to a
pipeline inlet after deductions for fuel usage and flare and the removal of nonhydrocarbon components to meet gas sales specifications. Estimates of fuel usage have been provided by Cairn.

The oil and condensate reserves estimated in this report are expressed in terms of 42 United States gallons per barrel. Oil reserves are to
be recovered by conventional field operations. Condensate reserves are to be recovered by normal field separation.

Data available
through January 2016 were used to prepare the estimates shown herein. However, Cairn provided the actual cumulative production as of March 31, 2016, to be used for the fields reported herein. Estimated gross oil, gas, and condensate
production was deducted from gross ultimate recovery to arrive at estimates of gross reserves shown herein.

The gross and net proved
reserves evaluated herein are presented in Tables 1 and 2, respectively. A reconciliation of the net proved oil and condensate and sales gas reserves, as of March 31, 2016, is shown in Table 3.



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DEGOLYER AND MACNAUGHTON



The estimated gross and net proved developed, proved undeveloped, and total proved oil and
condensate and sales gas reserves, as of March 31, 2016, of the properties evaluated herein are summarized as follows, expressed in millions of barrels (MMbbl) and billions of cubic feet (Bcf):



|                         |         |  |                    |  |        |                          |  |  |                |  |  |                          |       |  |                |  |       |       |  |  |       |  |  |       |       |  |     |  |       |       |  |  |         |  |  |  |        |  |  |  |        |  |  |  |       | 
|------------------------ | ------- |  | ------------------ |  | ------ | ------------------------ |  |  | -------------- |  |  | ------------------------ | ----- |  | -------------- |  | ----- | ----- |  |  | ----- |  |  | ----- | ----- |  | --- |  | ----- | ----- |  |  | ------- |  |  |  | ------ |  |  |  | ------ |  |  |  | ----- | 
|Proved Developed         |         |  | Proved Undeveloped |  |        | Total Proved             | 
|Oil andCondensate(MMbbl) |         |  | Sales Gas(Bcf)     |  |        | Oil andCondensate(MMbbl) |  |  | Sales Gas(Bcf) |  |  | Oil andCondensate(MMbbl) |       |  | Sales Gas(Bcf) | 
|Gross                    |         |  | Net                |  |        | Gross                    |  |  | Net            |  |  | Gross                    |       |  | Net            |  |       | Gross |  |  | Net   |  |  | Gross |       |  | Net |  |       | Gross |  |  | Net     | 
|                         |         |  |                    |  |        |                          |  |  |                |  | 
|                         | 165.429 |  |                    |  | 76.538 |                          |  |  | 12.170         |  |  |                          | 4.471 |  |                |  | 3.593 |       |  |  | 1.562 |  |  |       | 2.887 |  |     |  | 1.042 |       |  |  | 169.022 |  |  |  | 78.100 |  |  |  | 15.057 |  |  |  | 5.513 | 



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DEGOLYER AND MACNAUGHTON



VALUATION of RESERVES

This report has been prepared using prices and costs and future price and cost assumptions
specified by Cairn. Future prices were estimated using guidelines established by the SEC and the Financial Accounting Standards Board (FASB).

All economic information provided by Cairn has been expressed in United States dollars (U.S.$) or
Indian rupees (Rs.), and all revenue estimates included herein are expressed in Rs. using an exchange rate of Rs.66.33 per U.S.$1.00.

Revenue values in this report have been estimated for the properties using fiscal terms and economic
parameters provided by Cairn. A discussion of the fiscal terms and other economic parameters follows.

Oil and
Condensate Prices

Cairn has represented that the oil and condensate prices were
based on a 12-month average price, calculated as the unweighted average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the
reporting period, unless prices are defined by contractual agreements. All oil and condensate estimated herein is sold under contractual agreements. The volume-weighted average adjusted product price
attributable to estimated proved reserves was U.S.$40.79 per barrel for oil and condensate, based on a 12-month average Brent reference price of U.S.$47.44
per barrel. Cairn supplied differentials by field to the Brent reference price, and these prices were held constant for the lives of the properties.

Gas Prices

Cairn has represented that the gas prices are defined by contractual agreements
based on specific market conditions. The volume-weighted average adjusted product price attributable to estimated proved reserves was U.S.$7.29 per
thousand cubic feet. The average contract prices for each contract area were held constant for the lives of the properties.



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DEGOLYER AND MACNAUGHTON



Operating Expenses and Capital Costs

Estimates of future operating expenses and capital costs were based on information provided by Cairn.
This information included historical costs as well as operating expense and capital cost estimates for future development. Estimates of future operating expenses and capital
costs, either higher or lower than the Cairn development plan estimates, may have been made in order to conform to the respective reserves cases.

Abandonment Costs

Abandonment cost estimates were provided by Cairn for each
field or contract area and were included as capital costs through escrow payments over the life of the remaining reserves.

All cost estimates were held constant for the life of the evaluation (March 2016 terms).

Discussion of Fiscal Terms

RJ-ON-90/1 PSC
(Rajasthan)

Cairn has represented that under the terms of the PSC signed with the GOI,
the Contractor (Cairn and its partners) has the right to recover costs and share in the profit proceeds with the GOI. The Licensee (ONGC) pays royalties of 20
percent on the wellhead value of oil and condensate sales and 10 percent on the wellhead value of gas sales. The Contractor is liable for a production tax (termed cess) of 20
percent on the value of oil produced. Royalties and cess are considered allowable costs for cost recovery purposes. Profits are shared based on a sliding scale
tied to the ratio of cumulative revenues divided by cumulative investments (exploration and development). Income taxes are assessable at statutory rates for domestic and foreign companies (Cairns
interests are held by two entities: one domestic entity and one foreign entity).



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CB/OS-2 PSC

Cairn has represented that under the terms of the PSC signed with the GOI, the Contractor
has the right to recover costs and share in the profit proceeds with the GOI. The Contractor is not responsible for royalties or cess under the terms of this contract.
Profits are shared based on a sliding scale tied to the after-tax rate of return. Income taxes are assessable at statutory rates for domestic companies.

PKGM-1 License Area (Ravva)

Cairn has represented that under the terms of the PSC signed with the GOI, the Contractor
has the right to recover costs and share in the profit proceeds with the GOI. The Contractor pays royalties of Rs.481 per metric ton on oil sales and 10 percent on the
wellhead value of gas sales. The Contractor is also liable for a cess of Rs.927 per metric ton of oil produced. Royalties and cess are considered allowable costs for cost
recovery purposes. Profits are shared based on a sliding scale tied to the after-tax rate of return. Income taxes are assessable at statutory rates for domestic companies.

The estimated future net revenue and present worth of the future net revenue at a discount rate of 10
percent to be derived from the proved developed and total proved net reserves evaluated herein, as of March 31, 2016, are presented below in millions of Indian rupees (MM Rs.) and
millions of United States dollars (MM U.S.$):



|                          |        |  |                                   |  |        |                           |  |  |                                   |  |  |                             |        |  |                                     |  |     |                             |  |  |                                     |  |  |  |     |  |  |  |     | 
|------------------------- | ------ |  | --------------------------------- |  | ------ | ------------------------- |  |  | --------------------------------- |  |  | --------------------------- | ------ |  | ----------------------------------- |  | --- | --------------------------- |  |  | ----------------------------------- |  |  |  | --- |  |  |  | --- | 
|Proved Developed          |        |  | Total Proved                      |  |        | Proved Developed          |  |  | Total Proved                      | 
|Future NetRevenue(MM Rs.) |        |  | PresentWorth at10 Percent(MM Rs.) |  |        | Future NetRevenue(MM Rs.) |  |  | PresentWorth at10 Percent(MM Rs.) |  |  | Future NetRevenue(MM U.S.$) |        |  | PresentWorth at10 Percent(MM U.S.$) |  |     | Future NetRevenue(MM U.S.$) |  |  | PresentWorth at10 Percent(MM U.S.$) | 
|                          |        |  |                                   |  |        |                           | 
|                          | 60,891 |  |                                   |  | 53,064 |                           |  |  | 62,525                            |  |  |                             | 54,450 |  |                                     |  | 918 |                             |  |  | 800                                 |  |  |  | 943 |  |  |  | 821 | 

Standardized measure of discounted future net cash flows (SMV) and changes
therein relating to proved reserves, as of March 31, 2016, are shown in Table 4. The SMV is the net present worth discounted at 10 percent.



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In our opinion, the information relating to estimated proved reserves, estimated future
net revenue from proved reserves, and present worth of estimated future net revenue from proved reserves of oil, condensate, and gas contained in this report has been prepared in accordance with Paragraphs
932-235-50-4 through 932-235-50-7, 932-235-50-9, 932-235-50-30, and 932-235-50-31 of the Accounting Standards Update 932-235-50, Extractive Industries OilandGas(Topic932):OilandGasReserveEstimationand Disclosures(January 2010) of the Financial
Accounting Standards Board and Rules 4-10(a) (1)-(32) of Regulation S-X and Rules 302(b), 1201, 1202(a) (1), (2), (3), (4), (8)(i), (ii), and (v)-(x), and
1203(a) of Regulation S-K of the Securities and Exchange Commission.

To the extent the above-enumerated
rules, regulations, and statements require determinations of an accounting or legal nature, we, as engineers, are necessarily unable to express an opinion as to whether the above-described information is in accordance therewith
or sufficient therefor.



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DEGOLYER AND MACNAUGHTON



SUMMARY and CONCLUSIONS

The estimated net proved developed,
proved undeveloped, and total proved oil and condensate, sales gas, and oil equivalent reserves, as of March 31, 2016, of certain fields attributable
to the interests of Cairn and located in India are summarized as follows, expressed in millions of barrels (MMbbl), billions of cubic feet (Bcf), and millions of barrels of oil equivalent
(MMboe):



|                   |  |                          |        |  |               |  |       |                      |  |  |        | 
|------------------ |  | ------------------------ | ------ |  | ------------- |  | ----- | -------------------- |  |  | ------ | 
|                   |  | Net Reserves             |       
|                   |  | Oil andCondensate(MMbbl) |        |  | SalesGas(Bcf) |  |       | OilEquivalent(MMboe) | 
|                   |  |                          |       
|Proved Developed   |  |                          | 76.538 |  |               |  | 4.471 |                      |  |  | 77.284 | 
|Proved Undeveloped |  |                          | 1.562  |  |               |  | 1.042 |                      |  |  | 1.735  | 
|                   |  |                          |        |  |               |  |       |                      |  |  |        | 
|                   |  |                          |       
|Total Proved       |  |                          | 78.100 |  |               |  | 5.513 |                      |  |  | 79.019 | 



|Note: | Sales gas is converted to oil equivalent using an energy equivalent factor of 6,000 cubic feet of gas per 1 barrel of oil equivalent.
|----- | -------------------------------------------------------------------------------------------------------------------------------------

Estimates of the present worth derived from the proved developed and total proved reserves
of Cairns net petroleum interests, as of March 31, 2016, discounted at a rate of 10 percent and expressed in millions of Indian rupees (MM Rs.) and millions of United
States dollars (MM U.S.$), are presented in the following table:



|                 |  |                                    |        |  |                                      |  |     | 
|---------------- |  | ---------------------------------- | ------ |  | ------------------------------------ |  | --- | 
|                 |  | Present Worth at10 Percent(MM Rs.) |        |  | Present Worth at10 Percent(MM U.S.$) | 
|                 |  |                                   
|Proved Developed |  |                                    | 53,064 |  |                                      |  | 800 | 
|Total Proved     |  |                                    | 54,450 |  |                                      |  | 821 | 

While the oil and gas industry may be
subject to regulatory changes from time to time that could affect an industry participants ability to recover its oil and gas reserves, we are not aware of any such governmental
actions which would restrict the recovery of the March 31, 2016, estimated oil and gas reserves.



17



---

DEGOLYER AND MACNAUGHTON



DeGolyer and MacNaughton is an independent petroleum engineering consulting firm that has
been providing petroleum consulting services throughout the world since 1936. Our fees were not contingent on the results of our evaluation. This report has been prepared at the request of Vedanta Limited. DeGolyer and MacNaughton has used all
assumptions, procedures, data, and methods that it considers necessary to prepare this report.



Submitted,LOGODeGOLYER and MacNAUGHTONTexas Registered Engineering Firm F-716


SIGNED: April 29, 2016



LOGO



LOGOThomas C. Pence, P.E.Senior Vice PresidentDeGolyer and MacNaughton




18



---

| |  |                                                                                                                            |  |     
| |  | -------------------------------------------------------------------------------------------------------------------------- |  | ----
| |  | TABLE 1
GROSS PROVED RESERVES as
of MARCH 31, 2016
for CERTAIN
FIELDS in
INDIA with interests
owned by CAIRN INDIA LIMITED |  | LOGO





|                      |  |                          |         |  |                    |  |        |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |         |  |  |  |        |  |  |  |         | 
|--------------------- |  | ------------------------ | ------- |  | ------------------ |  | ------ | -------------------- |  |  | ------------------------ |  |  | ------------- | ----- |  | -------------------- |  | ----- | ------------------------ |  |  | ------------- |  |  | -------------------- | ------- |  |  |  | ------ |  |  |  | ------- | 
|                      |  | Gross Reserves           |        
|                      |  | Proved Developed         |         |  | Proved Undeveloped |  |        | Total Proved         | 
|Area Field            |  | Oil andCondensate(MMbbl) |         |  | SalesGas(Bcf)      |  |        | OilEquivalent(MMboe) |  |  | Oil andCondensate(MMbbl) |  |  | SalesGas(Bcf) |       |  | OilEquivalent(MMboe) |  |       | Oil andCondensate(MMbbl) |  |  | SalesGas(Bcf) |  |  | OilEquivalent(MMboe) |        
|                      |  |                          |         |  |                    |  |        |                      | 
|CB/OS-2 PSC           |  |                          |         |  |                    |  |        |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |         |  |  |  |        |  |  |  |         | 
|CB-X                  |  |                          | 0.000   |  |                    |  | 0.000  |                      |  |  | 0.000                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 0.000   |  |  |  | 0.000  |  |  |  | 0.000   | 
|Guari                 |  |                          | 0.647   |  |                    |  | 0.330  |                      |  |  | 0.702                    |  |  |               | 0.000 |  |                      |  | 0.337 |                          |  |  | 0.056         |  |  |                      | 0.647   |  |  |  | 0.667  |  |  |  | 0.758   | 
|Lakshmi               |  |                          | 3.464   |  |                    |  | 3.142  |                      |  |  | 3.988                    |  |  |               | 0.921 |  |                      |  | 2.550 |                          |  |  | 1.346         |  |  |                      | 4.385   |  |  |  | 5.692  |  |  |  | 5.334   | 
|                      |  |                          |         |  |                    |  |        |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |         |  |  |  |        |  |  |  |         | 
|                      |  |                          |         |  |                    |  |        |                      | 
|Total CB/OS-2 PSC     |  |                          | 4.111   |  |                    |  | 3.472  |                      |  |  | 4.690                    |  |  |               | 0.921 |  |                      |  | 2.887 |                          |  |  | 1.402         |  |  |                      | 5.032   |  |  |  | 6.359  |  |  |  | 6.092   | 
|                      |  |                          |         |  |                    |  |        |                      | 
|RJ-ON-90/1PSG         |  |                          |         |  |                    |  |        |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |         |  |  |  |        |  |  |  |         | 
|Aishwariya            |  |                          | 19.031  |  |                    |  | 0.000  |                      |  |  | 19.031                   |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 19.031  |  |  |  | 0.000  |  |  |  | 19.031  | 
|Bhagyam               |  |                          | 14.055  |  |                    |  | 0.000  |                      |  |  | 14.055                   |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 14.055  |  |  |  | 0.000  |  |  |  | 14.055  | 
|Mangala               |  |                          | 115.174 |  |                    |  | 0.000  |                      |  |  | 115.174                  |  |  |               | 2.672 |  |                      |  | 0.000 |                          |  |  | 2.672         |  |  |                      | 117.846 |  |  |  | 0.000  |  |  |  | 117.846 | 
|N-E                   |  |                          | 0.362   |  |                    |  | 0.000  |                      |  |  | 0.362                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 0.362   |  |  |  | 0.000  |  |  |  | 0.362   | 
|N-I                   |  |                          | 0.505   |  |                    |  | 0.000  |                      |  |  | 0.505                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 0.505   |  |  |  | 0.000  |  |  |  | 0.505   | 
|Raagashwari (Shallow) |  |                          | 0.771   |  |                    |  | 0.000  |                      |  |  | 0.771                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 0.771   |  |  |  | 0.000  |  |  |  | 0.771   | 
|Raagashwari Deep      |  |                          | 1.372   |  |                    |  | 6.570  |                      |  |  | 2.467                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 1.372   |  |  |  | 6.570  |  |  |  | 2.467   | 
|Saraswati             |  |                          | 0.529   |  |                    |  | 0.000  |                      |  |  | 0.529                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 0.529   |  |  |  | 0.000  |  |  |  | 0.529   | 
|                      |  |                          |         |  |                    |  |        |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |         |  |  |  |        |  |  |  |         | 
|                      |  |                          |         |  |                    |  |        |                      | 
|Total RJ-ON-90/1 PSC  |  |                          | 151.799 |  |                    |  | 6.570  |                      |  |  | 152.894                  |  |  |               | 2.672 |  |                      |  | 0.000 |                          |  |  | 2.672         |  |  |                      | 154.471 |  |  |  | 6.570  |  |  |  | 155.566 | 
|                      |  |                          |         |  |                    |  |        |                      | 
|PKGM-1 License Area   |  |                          |         |  |                    |  |        |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |         |  |  |  |        |  |  |  |         | 
|Ravva                 |  |                          | 9.519   |  |                    |  | 2.128  |                      |  |  | 9.874                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 9.519   |  |  |  | 2.128  |  |  |  | 9.874   | 
|                      |  |                          |         |  |                    |  |        |                      | 
|Grand Total           |  |                          | 165.429 |  |                    |  | 12.170 |                      |  |  | 167.458                  |  |  |               | 3.593 |  |                      |  | 2.887 |                          |  |  | 4.074         |  |  |                      | 169.022 |  |  |  | 15.057 |  |  |  | 171.532 | 



|Note: | Sales gas is converted to oil equivalent using a factor of 6,000 cubic feet of gas per 1 barrel of oil equivalent.
|----- | ------------------------------------------------------------------------------------------------------------------

These data accompany the report of DeGolyer and MacNaughton and are subject to its specific conditions.



---

| |  |                                                                                                                 |  |     
| |  | --------------------------------------------------------------------------------------------------------------- |  | ----
| |  | TABLE 2
NET PROVED RESERVES as
of MARCH 31, 2016
for CERTAIN AREAS
in INDIA
attributable to CAIRN
INDIA LIMITED |  | LOGO



|                    |  |                          |        |  |                    |  |       |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |        |  |  |  |       |  |  |  |        | 
|------------------- |  | ------------------------ | ------ |  | ------------------ |  | ----- | -------------------- |  |  | ------------------------ |  |  | ------------- | ----- |  | -------------------- |  | ----- | ------------------------ |  |  | ------------- |  |  | -------------------- | ------ |  |  |  | ----- |  |  |  | ------ | 
|                    |  | Net Reserves             |       
|                    |  | Proved Developed         |        |  | Proved Undeveloped |  |       | Total Proved         | 
|Area                |  | Oil andCondensate(MMbbl) |        |  | SalesGas(Bcf)      |  |       | OilEquivalent(MMboe) |  |  | Oil andCondensate(MMbbl) |  |  | SalesGas(Bcf) |       |  | OilEquivalent(MMboe) |  |       | Oil andCondensate(MMbbl) |  |  | SalesGas(Bcf) |  |  | OilEquivalent(MMboe) |       
|                    |  |                          |        |  |                    |  |       |                      | 
|CB/OS-2 PSC         |  |                          | 1.295  |  |                    |  | 1.149 |                      |  |  | 1.487                    |  |  |               | 0.331 |  |                      |  | 1.042 |                          |  |  | 0.504         |  |  |                      | 1.626  |  |  |  | 2.191 |  |  |  | 1.991  | 
|RJ-ON-90/1PSC       |  |                          | 73.902 |  |                    |  | 3.055 |                      |  |  | 74.411                   |  |  |               | 1.231 |  |                      |  | 0.000 |                          |  |  | 1.231         |  |  |                      | 75.133 |  |  |  | 3.055 |  |  |  | 75.642 | 
|PKGM-1 License Area |  |                          | 1.341  |  |                    |  | 0.267 |                      |  |  | 1.386                    |  |  |               | 0.000 |  |                      |  | 0.000 |                          |  |  | 0.000         |  |  |                      | 1.341  |  |  |  | 0.267 |  |  |  | 1.386  | 
|                    |  |                          |        |  |                    |  |       |                      |  |  |                          |  |  |               |       |  |                      |  |       |                          |  |  |               |  |  |                      |        |  |  |  |       |  |  |  |        | 
|                    |  |                          |        |  |                    |  |       |                      | 
|Total               |  |                          | 76.538 |  |                    |  | 4.471 |                      |  |  | 77.284                   |  |  |               | 1.562 |  |                      |  | 1.042 |                          |  |  | 1.735         |  |  |                      | 78.100 |  |  |  | 5.513 |  |  |  | 79.019 | 



|Note: | Sales gas is converted to oil equivalent using a factor of 6,000 cubic feet of gas per 1 barrel of oil equivalent.
|----- | ------------------------------------------------------------------------------------------------------------------

These data accompany the report of DeGolyer and MacNaughton and are subject to its specific conditions.



---

| |  |                                                                                                                                        |  |     
| |  | -------------------------------------------------------------------------------------------------------------------------------------- |  | ----
| |  | TABLE 3
RECONCILIATION of NET PROVED RESERVES
as of MARCH 31,
2016 for CERTAIN
PROPERTIES in
INDIA attributable
to CAIRN INDIA LIMITED |  | LOGO



|                                                               |  |                          |          |  |               |  |         |                      |  |  |          | 
|-------------------------------------------------------------- |  | ------------------------ | -------- |  | ------------- |  | ------- | -------------------- |  |  | -------- | 
|                                                               |  | Oil andCondensate(MMbbl) |          |  | SalesGas(Bcf) |  |         | OilEquivalent(MMboe) | 
|                                                               |  |                          |         
|Proved Developed and Undeveloped Reserves as of March 31, 2015 |  |                          | 90.090   |  |               |  | 4.890   |                      |  |  | 90.905   | 
|                                                               |  |                          |         
|Revisions                                                      |  |                          | 20.699   |  |               |  | 4.954   |                      |  |  | 21.525   | 
|Improved Recovery                                              |  |                          | 0.000    |  |               |  | 0.000   |                      |  |  | 0.000    | 
|Purchases or (Sales) of Minerals in Place                      |  |                          | 0.000    |  |               |  | 0.000   |                      |  |  | 0.000    | 
|Extensions and Discoveries                                     |  |                          | 0.000    |  |               |  | 0.000   |                      |  |  | 0.000    | 
|Annual Production                                              |  |                          | (32.689) |  |               |  | (4.331) |                      |  |  | (33.411) | 
|                                                               |  |                          |         
|Proved Developed and Undeveloped Reserves as of March 31, 2016 |  |                          | 78.100   |  |               |  | 5.513   |                      |  |  | 79.019   | 
|                                                               |  |                          |         
|Proved Developed Reserves                                      |  |                          |          |  |               |  |         |                      |  |  |          | 
|March 31, 2015                                                 |  |                          | 73.940   |  |               |  | 3.550   |                      |  |  | 74.532   | 
|March 31, 2016                                                 |  |                          | 76.538   |  |               |  | 4.471   |                      |  |  | 77.284   | 



|Note: | Sales gas is converted to oil equivalent using a factor of 6,000 cubic feet of gas per 1 barrel of oil equivalent.
|----- | ------------------------------------------------------------------------------------------------------------------

These data accompany the report of DeGolyer and MacNaughton and are subject to its specific conditions.



---

| |  |                                                                                                                                                                                                           |  |     
| |  | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | ----
| |  | TABLE 4
STANDARDIZED MEASURE of DISCOUNTED FUTURE NET CASH FLOWS and CHANGES THEREIN relating to PROVED RESERVES
as of MARCH 31,
2016 for CERTAIN
PROPERTIES in
INDIA attributable
to CAIRN INDIA LIMITED |  | LOGO



|                                                                                                                                                                      |  |                    |           |  |                      |  |         | 
|--------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | ------------------ | --------- |  | -------------------- |  | ------- | 
|                                                                                                                                                                      |  | TotalProved(MMRs.) |           |  | TotalProved(MMU.S.$) | 
|Future cash inflows                                                                                                                                                   |  |                    | 212,729   |  |                      |  | 3,207   | 
|Future production costs                                                                                                                                               |  |                    | 127,002   |  |                      |  | 1,915   | 
|Future development costs                                                                                                                                              |  |                    | 22,492    |  |                      |  | 339     | 
|Future income tax expenses                                                                                                                                            |  |                    | 710       |  |                      |  | 11      | 
|Future net cash flows                                                                                                                                                 |  |                    | 62,525    |  |                      |  | 943     | 
|10% annual discount for estimated timing of cash flows                                                                                                                |  |                    | (8,075)   |  |                      |  | (122)   | 
|                                                                                                                                                                      |  |                   
|Standardized measure of discounted future net cash flows                                                                                                              |  |                    | 54,450    |  |                      |  | 821     | 
|                                                                                                                                                                      |  |                   
|The following are the principal sources of change in the standardized measure
of discounted future net cash flows during Fiscal Year 2015 (All values are in MM Rs.): |  |                    |           |  |                      |  |         | 
|                                                                                                                                                                      |  |                   
|Standardized Measure March 31, 2015                                                                                                                                   |  |                    | 157,369   |  |                      |  | 2,573   | 
|                                                                                                                                                                      |  |                   
|Sales and transfers of oil and gas produced, net of production costs                                                                                                  |  |                    | (40,465)  |  |                      |  | (610)   | 
|Net changes in prices and production costs                                                                                                                            |  |                    | (135,831) |  |                      |  | (2,048) | 
|Extensions, discoveries and improved recovery                                                                                                                         |  |                    | 0         |  |                      |  | 0       | 
|Development costs incurred during the period                                                                                                                          |  |                    | 8,910     |  |                      |  | 134     | 
|Revisions of previous quantity estimates                                                                                                                              |  |                    | 20,538    |  |                      |  | 310     | 
|Change in estimated development costs                                                                                                                                 |  |                    | 19,030    |  |                      |  | 287     | 
|Purchase or (Sales) of Minerals in Place                                                                                                                              |  |                    | 0         |  |                      |  | 0       | 
|Accretion of discount                                                                                                                                                 |  |                    | 17,060    |  |                      |  | 257     | 
|Net change in income taxes                                                                                                                                            |  |                    | 7,839     |  |                      |  | 118     | 
|                                                                                                                                                                      |  |                   
|Standardized Measure March 31, 2016                                                                                                                                   |  |                    | 54,450    |  |                      |  | 821     | 

Notes:



|1. | Indian Rupees (Rs.) were converted to United States dollars (U.S.$) using an exchange rate of 66.33 Rs. per U.S.$1.00; however, these totals may vary due to rounding.
|-- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------

|2. | For 2015, an exchange rate of 61.16 Rs. per U.S.$1.00 was used.
|-- | ---------------------------------------------------------------

These data accompany the
report of DeGolyer and MacNaughton and are subject to its specific conditions.