EMBARGOED FOR RELEASE AT 0700                                                            22 August 2017

CAIRN ENERGY PLC ("Cairn" or "Company" or "Group")

Half-Year Report Announcement

Simon Thomson, Chief Executive, Cairn Energy PLC said:

"Cairn continues to deliver strong progress across the business. 

In the North Sea, Kraken has commenced production and Catcher is scheduled for first oil later this year.  In Senegal, planning work has commenced on the phased development of the world class SNE field.

Cairn has also added to its exploration portfolio with exciting new opportunities in Norway, Ireland and Mexico creating additional drilling prospects in the near term.

With a strong balance sheet and imminent cashflows, Cairn remains well funded to create and capture value for our shareholders."

Senegal  

Ø Joint Venture (JV) planning underway for phased development of SNE field, Cairn targeting production rates of 75,000-125,000 barrels of oil per day (bopd) with first oil planned 2021-2023

Ø Updated overall SNE 2C oil resource base of ~563 million barrels of oil (mmbbls)*, with additional recoverable gas resources of more than 1 trillion cubic feet (TcF)

Ø Cairn estimates up to 25 wells planned in initial development phase, targeting ~240 mmbbls principally in S500 lower reservoir

Ø Subsequent development phases to target resource base in S400 upper reservoir

Ø Engagement with major FPSO and subsea contractors commenced prior to formal tendering process later this year

Ø Targeting Evaluation Report and Exploitation Plan submission to Government of Senegal in 2018 for Final Investment Decision (FID) before end of 2018

Ø Evaluation of potential further exploration opportunities underway, including in the shallower water Rufisque block

*ERC Equipoise Limited (ERCE) estimate

Exploration new ventures

Ø New licences acquired in three countries: Norway, Ireland and Mexico in 2017, with drilling expected in 2018-2020

Finance

Ø US$254 million (m) Group cash at 30 June 2017

Ø Norwegian tax receivable of US$29m in H2 2017

Ø Reserves Based Lending (RBL) bank facility remains undrawn with expected peak availability of US$350-400m and ~US$210m at year end 2017

Ø FlowStream US$75m cash proceeds received in H1 2017

Ø Remaining 2017 capex for Catcher and Kraken development projects of US$35m and US$75m

Ø Exploration and appraisal (E&A) expenditure across the portfolio of US$150m in H2 2017

Ø Following merger of Cairn India Limited (CIL) and Vedanta Limited (VL), Cairn holds ~5% of VL, valued at US$824m at 30 June 2017

Ø Cairn remains unable to access its ~5% shareholding of VL pending resolution of the Indian tax dispute and dividends receivable of US$105m are fully impaired following an order directing payment from VL to the Indian Income Tax Department (IITD)

Developments

Ø Kraken (Cairn 29.5% working interest (WI)) production commenced as anticipated in Q2 2017 with facilities commissioning and production ramp up underway. Plateau production 50,000 bopd in 2018 with ~15,000 bopd net to Cairn

Ø Catcher (Cairn 20% WI) targeting first oil by year end 2017** with FPSO well advanced in Singapore.  Plateau production 50,000 bopd with ~10,000 bopd net to Cairn

Ø Skarfjell (Cairn 20% WI) concept selection for field development, targeting FID in H1 2018. Expected plateau production 50,000 bopd with ~10,000 bopd net to Cairn

** Operator estimate

Enquiries to:

Webcast

There will be a live audio webcast of the results presentation available to view on the website (www.cairnenergy.com) at 9am BST. This can be viewed on PC, Mac, iPad, iPhone and Android mobile devices.

An 'on demand' version of the webcast will be available on the website as soon as possible after the event. This can be viewed on PC, Mac, iPad, iPhone and Android mobile devices.

Presentation 

The results presentation slides will be available on the website from 7am BST.

Conference all

You can listen to the results presentation by dialling in to a listen only conference call at 9am BST using the below dial-in details.

Dial-in Details:

United Kingdom (Local):                        020 3059 8125                                              

All other locations:                               +44 20 3059 8125

A recording of the conference call will be available from 22 August 2017 until 29 August 2017.

Recording Dial-in Details:

United Kingdom:                                   0121 260 4861                                                                  

United States:                                      1 844 2308 058      

All other locations:                                +44 121 260 4861

Passcode:                                           6576858#               

Transcript

A transcript of the presentation will be available on the website as soon as possible after the event.

Corporate & Finance Overview

Cairn's strategy is to deliver sustainable value growth for shareholders from a balanced portfolio of exploration, development and production assets.  Our exploration portfolio is primarily in frontier and emerging basins which offer the greatest value potential, funded from producing assets and balance sheet strength.  In the first half of 2017, we have made excellent progress on our strategic objectives and are well-positioned to deliver continued success.  We have created a strong platform for future growth with active positions in various geographies providing significant acreage of both technical and commercial value.

Cairn has financial flexibility with a strong balance sheet, available debt funding and cash flow coming on stream from North Sea developments.  Our sustainable business model provides the flexibility to leverage success, and we continue to optimise and where appropriate expand the asset base.

Current sources of funding include cash of US$254m at mid year, a Norwegian tax receivable of US$29m and the RBL bank facility with US$210m expected to be available this year. Near term uses of capital include US$110m of expected capital expenditure on the Kraken and Catcher developments in the UK to the end 2017.  Kraken is now in production and Catcher is scheduled to be on stream and cashflow generative around year end.  Expected exploration and appraisal expenditure in H2 2017 is US$150m across the portfolio.

Operational Review

Senegal

Eleven wells have been drilled in three years in Senegal.  Following two basin opening discoveries, SNE-1 and FAN-1, in 2014 and approval of an extensive appraisal plan by the Government of Senegal in 2015, Cairn and its JV partners successfully completed a further four exploration and appraisal wells ahead of schedule and under budget in 2016. The third phase of drilling commenced in 2017 with a programme of five wells now complete.

Having established a significant and growing resource base, the objective of the appraisal and exploration programme this year was to further define the SNE field for development and target additional exploration upside on the acreage.

The programme has substantially improved Cairn's understanding of the areal extent of the SNE field, which covers ~350km², confirming two distinct horizons with a stacked series of S400 upper reservoirs overlying S500 lower reservoirs.  This well data provides key connectivity and deliverability information from the reservoirs and enables calibration of the reservoir model, critical for optimising recovery factors by ensuring development wells are designed appropriately in number, placement and orientation.

The 2017 drilling campaign consisted of the following sequence of wells:

Ø   SNE-5 targeted a location in the upper reservoirs where two principal units are located within the oil leg. The main reservoir units, pressure data and fluid contacts matched previous SNE wells and multiple samples of oil and gas were recovered during wireline logging and drill stem tests with analysis indicating oil of similar quality.

Ø   VR-1 encountered some of the best quality reservoirs found to date some 5km from the SNE-1 discovery.  The well established that the targeted lower reservoirs are within the oil column, confirming reservoir presence, fluid contacts and fluid quality in line with previous results. Analysis indicates the quality of the lower reservoir section is better and slightly thicker than anticipated.  Results confirm the predictability of the mapped reservoir over a wide area giving confidence in the reservoir engineering models.   

Ø   SNE-6, together with the successful SNE-5 well, was intended to flow oil from one of the principal units in the upper reservoirs and demonstrate connectivity between the two wells.  Pressure data confirmed good connectivity and multiple samples of oil taken indicated oil of a similar quality to previous wells.  

Ø   FAN South-1 encountered hydrocarbon bearing reservoir and oil samples were obtained with preliminary analysis indicating 31° API oil quality.  Further work is underway to integrate the discovery with FAN-1 to establish the potential commerciality of the deep water, basinal resource seen in the two wells.

Ø  SNE North-1 encountered oil and gas in the primary objective and oil in the deeper secondary objective, in a separate accumulation to the SNE field.  A full set of oil, water and gas samples were recovered with preliminary analysis indicating a slightly lighter oil type of 35° API. Further work is being undertaken to establish the potential commerciality of the discovery and to integrate results with block wide data gathered to date.

Information from all three phases of drilling and additional seismic work is being integrated to build and refine the understanding of the full hydrocarbon potential of the area.  The updated independent third party estimate of gross recoverable contingent resource for SNE is 1C 346 mmbbls, 2C 563 mmbbls and 3C 998 mmbbls.

The JV has endorsed the foundation development concept of a standalone FPSO with subsea wells and expansion capability.  Detailed planning is now underway for a phased development of the SNE field.

Cairn estimates that the first phase of the SNE development will target ~240mmbbls principally in the S500 lower reservoirs with an initial target plateau of 75,000-125,000 bopd (dependent on FPSO capacity).  The initial well count is up to 25 with oil producers, water and gas injectors.  First oil is targeted from 2021 to 2023.

The subsequent development phases will target the S400 upper reservoirs and additional areas, with current Cairn estimates of an additional well count of 40 wells, with 20 producers and 20 water injectors.

The current SNE development plans assume gas re-injection during initial development with the potential for gas export in later phases.  It is estimated that the SNE field holds more than 1 TcF recoverable non associated gas and 0.3 TcF of associated gas.  

The concept selection and engagement with major contractors has commenced prior to formal tendering for the FPSO and subsea infrastructure later this year.

The transfer of operatorship to Woodside for the development phase is planned to take place next year with Cairn continuing exploration activities on the acreage.  The JV plan to submit an evaluation report and exploitation plan to the Government of Senegal in 2018.  The Front End Engineering and Design (FEED) is also planned to commence next year with a FID targeted before the end of 2018.

Alongside development planning, the JV continues to focus on the exploration potential around the SNE discovery where significant untested prospectivity remains with prolific oil prone source rock, excellent reservoir development and a good working seal.  On the Rufisque and Sangomar offshore blocks, the JV is maturing multiple prospects on newly processed 3D seismic data with a view to potential further exploration drilling, which in a success case could potentially support a standalone development.

Cairn (Operator) has a 40% WI in three blocks offshore Senegal (Sangomar Deep, Sangomar Offshore and Rusique Offshore) alongside partners, Woodside 35% WI, FAR Ltd 15% WI and the Senegal National Oil Company, Petrosen 10% WI.

International

Cairn's exploration focus is on the Atlantic Margin where, in addition to Senegal, the Company has extensive acreage offering the potential for material discoveries and high prospectivity.

Cairn was delighted to secure interests in two licences in the Mexico offshore bid round in H1 2017.  The licences (one operated and one non-operated) cover an area of ~1,200km² located in the shallow water Gulf of Mexico, directly analogous to recent world class discoveries.  Multiple attractive prospects in a variety of play types have been identified within this highly prolific, proven hydrocarbon province which has recently opened to international oil companies and is significantly underexplored relative to the US Gulf of Mexico.  Cairn anticipates exploration drilling to commence in 2019-2020 with four wells across the two blocks.

Cairn also has a growing acreage position offshore Ireland.  The play opening Druid/Drombeg well is underway which is a high impact, dual target, frontier exploration well operated by Providence Resources (Cairn 30% WI). The well penetrated the Paleocene Druid prospect within the pre-drill depth prognosis. Preliminary petrophysical analysis of 'Logging While Drilling' data indicates that the Druid prospect comprised porous water-bearing reservoir. Operations are now proceeding to assess the deeper Lower Cretaceous Drombeg exploration prospect target, situated ~1,000m beneath Druid.

Additionally in Ireland, Cairn farmed into LO 16/19 with 70% WI and Operatorship, partnering with Europa Oil & Gas.  Cairn was previously awarded the adjacent LO 16/18 in the 2016 Atlantic Licensing Round.  A 3D seismic survey is ongoing over both licence option blocks and will be processed in 2018. Cairn has also acquired a 20% WI option on the FEL 2/14 Avalon licence in the Southern Porcupine Basin.

In Western Sahara, we commenced the acquisition of 3D seismic with Operator, Kosmos Energy, following a new Petroleum Agreement in 2016. 

Developments

In the UK and Norway we have made significant progress in our high quality development assets in the year to date. The Kraken and Catcher developments are two of the largest development projects in the UK North Sea.  The Skarfjell discovery in Norway is scheduled for JV FID in H1 2018. These three projects are a key part of Cairn's strategy to build steady future cash flows to sustain our ongoing investment strategy.

Cairn production from the North Sea commenced in Q2 2017 with first oil from the Kraken field.  Production facilities commissioning and production ramp up is underway with plateau production in 2018 expected to be 50,000 bopd, ~15,000 bopd net to Cairn.  Seventeen wells have been drilled and completed to date (nine producers and eight injectors). Production capacity is being brought online in a phased manner in order to maximise long term productivity and value. The Operator, EnQuest, estimates that capex savings of 22% have been achieved on the project compared to the sanction estimate.

Cairn's production base will increase when the Catcher development is on stream with first oil scheduled by the Operator, Premier Oil, by year end 2017.  The FPSO is well advanced in the Keppel yard in Singapore with sail away to the North Sea targeted for later this month.  Catcher is anticipated to deliver plateau production of 50,000 bopd with ~10,000 bopd net to Cairn. Twelve wells (eight producers and four injectors) have been drilled to date with reservoir quality in line with or better than prognosis.  The operator estimates that capex savings of 29% have been achieved on the project compared to the sanction estimate.

In the Norwegian Sea, the Skarfjell development has production potential of 50,000 bopd with ~10,000 bopd net to Cairn.  The JV has selected a field development concept as a subsea tie back to the nearby Gjøa platform and the FEED has commenced.  Skarfjell is a light oil development which also offers significant adjacent acreage opportunities with tie back opportunities.

UK and Norway Exploration

Cairn has built a strong position in the UK and Norway by acquiring exploration, appraisal and development assets and participating in licencing rounds. The strategy is to maintain and grow a strong prospect inventory capable of increasing resources and reserves, providing material exploration upside and bringing discoveries into production. Plans are underway for a potential drilling campaign of up to ten wells (two as Operator), subject to partner approval, in 2017-2019 targeting over one billion barrels gross unrisked potential resource across a variety of plays in the UK and Norway, including in the Barents Sea.   

India

Following the merger of CIL and VL, Cairn holds ~5% of VL, valued at US$824m at 30 June 2017. Cairn remains unable to access its ~5% shareholding of VL pending the outcome of the Indian tax dispute and dividends receivable of US$105m are fully impaired following an order directing payment from VL to the IITD.

Financial Review

Overview

First oil production commenced from the Kraken field in late June, with Catcher production scheduled to be on stream by the end of 2017.  The Group's funding position was enhanced during the first half of 2017 with the completion of a NOK 500 million (~US$60m) Exploration Finance Facility (EFF) which allows the Company to borrow against Norwegian tax refunds on exploration expenditure, and US$75m proceeds from a stream agreement with FlowStream Commodities in exchange for an initial 4.5% share of production from Kraken (stepping down to a 1.35% share once FlowStream achieves a 10% return).

Cairn successfully completed three exploration and appraisal wells in the first six months of 2017 in Senegal, with a further two wells completed in July and August.  Exceptional operational performance has resulted in all wells being drilled under budget. 

Cash

Cairn had cash and cash equivalents of US$254m at 30 June 2017, representing a net cash outflow of US$81m over the six month period. 

Exploration expenditure in the period included Senegal exploration costs of US$50m as Cairn completed the SNE-5 and SNE-6 appraisal wells and the V-R 1 exploration and appraisal well with the FAN South-1 exploration well completing in July.  The final well in the current programme, the SNE North-1 exploration well completed in August.

In Ireland, the dual prospect exploration well targeting the Druid and Drombeg prospects commenced in July.  The Druid prospect reached target in August failing to discover commercial hydrocarbons, drilling continues towards the Drombeg prospect. Exploration costs include US$7m in respect of this well.

Development expenditure in the period related to costs of the Kraken and Catcher developments.  The remaining Catcher development carry in Cairn's favour resulting from the farm-down to Dyas in 2015 was fully used by January 2017.

Forecast development expenditure for the second half of 2017, taking the UK development projects through to cashflow generation, is US$110m; and remaining currently committed drilling exploration and appraisal expenditure for the second half of 2017 is estimated at US$150m, predominantly in Senegal.

Cairn remains fully funded to meet all existing commitments at the Balance Sheet date. 

US$22m of loans were drawn under the Group's EFF in Norway.  The facility allows the Group to draw against tax refunds receivable on qualifying exploration and operating costs incurred in Norway.  Cairn's RBL bank facility remains undrawn, with peak debt availability forecast to be in the range of US$350m to US$400m, and availability by year end 2017 expected to reach ~US$210m. 

The Group received US$75m less costs from FlowStream under the initial stream agreement concluded in March.  FlowStream is entitled to a share of 4.5% of Kraken production, which reduces to 1.35% after FlowStream achieve a 10% return and would further reduce to 0.675% if FlowStream achieved a 15% return.  FlowStream's sole recourse for the payment under the stream agreement is to its production rights from Kraken.

Oil and Gas Assets

Exploration and Appraisal Assets

Senegal

Additions in the period include the SNE-5 and SNE-6 appraisal wells, the VR-1 exploration and appraisal well and FAN South-1 exploration well.

UK and Norway

Additions were spread across the Group's portfolio of licences, focussing on future exploration targets.  A potential of up to ten exploration wells are planned in 2018-2019.

International

The Group's international additions included the farm-in to FEL 2/14 in Ireland containing the Druid and Drombeg prospects. 

Unsuccessful exploration

Unsuccessful exploration write offs include US$6m following the Group's exit from Malta, planned relinquishments in the UK and Norway and the write-down of inventory.

Oil and Gas Assets - Development/Producing Assets

Development additions in the period totalled US$88m; US$52m on Kraken where first oil production commenced in June 2017 with the remaining US$36m on Catcher. 

First oil production in Kraken led to the commencement of the lease for the FPSO, with associated additions of US$201m, equal to the present value of minimum lease commitments recognised as a liability at the same point.

The Group's development assets are tested for impairment at the year-end or where there are indicators that impairment may exist.  No new indicators of impairment have been identified since the December 2016 year-end and therefore no formal impairment test was conducted at June 2017. 

Foreign exchange movements

The Group's development assets are held in a GBP functional subsidiary, which is translated to US$ on consolidation.  The first six months of 2017 have seen a modest recovery in GBP against the US$ after last year's falls following the EU referendum result, leading to exchange gains of US$52m over the period. 

Available for Sale Financial Assets - Investment in Cairn India/Vedanta Limited and related Dividend income

The merger of CIL with VL completed in April 2017.  Under the terms of the merger, Cairn received ordinary shares and preference shares in VL in exchange for the Group's residual ~10% shareholding in CIL.  As a result Cairn now has a shareholding of ~5% in VL, valued at US$824m at 30 June.  Cairn remains unable to access the value of this investment pending the outcome of its ongoing Indian tax dispute.

The merger of CIL with VL led to an accounting loss of US$33m on the difference in market value of the Group's holding in CIL and VL immediately before and after the merger respectively. The derecognition of the CIL shares led to a recycling of the surplus on valuation of the CIL shares held in equity of US$436m. Net of the merger accounting loss, this results in a net gain of US$403m presented in the Income Statement.

Prior to the merger, CIL declared a final dividend of US$52m, bringing total amounts of dividends due to the Company from CIL to US$105m.  Subsequent to the merger, the IITD seized this dividend income due to Cairn in partial settlement of the tax demand issued in relation to the retrospective tax dispute.  Cairn has therefore fully provided against the US$105m, pending conclusion of the dispute. 

Cairn is seeking restitution under the UK India Bilateral Investment Treaty for losses resulting from the attachment of its shares in VL and failure to treat the Company and its investments fairly and equitably.  Tribunal proceedings are well progressed and Cairn has a high level of confidence in its case.  In addition to resolution of the retrospective tax dispute, Cairn's request for relief to the arbitration panel is seeking damages equal to the value of Group's residual shareholding in VL at the time it was attached (approximately US$1 billion). 

A tax refund in respect of financial year 2011-12 in the amount of INR 15.9bn (~US$249m) which became due to Cairn as a consequence of a successful appeal by the Group has also been directed to the IITD to be set against the deemed 2006-7 liability and Cairn's claims under the international arbitration have been adjusted to include this.

Results for the period

Revenue

Revenue receivable relates to royalties due from Petrochina on producing fields in Mongolia.  Following successful international arbitration proceedings Cairn was able to demonstrate title to the royalties and the basis of calculation for the amounts due.  Amounts due to Cairn for the period to September 2016 were received in July 2017. No revenue was recognised in the period relating to production from Kraken.

Pre-award costs   

Costs in the six months to 30 June 2017 include US$17m following new opportunities in the Barents Sea and US$10m of other opportunities in the UK & Norway region.  US$7m of spend on new opportunities in the International portfolio included work on the Mexico bid round that resulted in the award of two blocks to Cairn.

Unsuccessful exploration costs

Unsuccessful exploration costs include the relinquishment of licences in Malta and the write down of inventory.

Administration costs

The reduction in Group administration costs on a year-on-year basis over the first six months of the year is a result of prior year costs incurred in relation to the ongoing arbitration.

Cairn India/Vedanta Limited investment and dividends

As described above, the merger of CIL and VL created a net gain on derecognition of CIL investments of US$403m.   The seizure of dividend monies due to Cairn, including US$52m in the current period, resulted in a provision of US$105m.

Taxation

As the Group's activity continued to focus on assets in the exploration, appraisal and development phases, the Group generated no production income and as such no corporation tax was payable in the period. At 30 June 2017, Cairn had total UK ring fence losses of US$799m.  US$616m of losses are recognised as deferred tax assets (at the applicable UK tax rate of 40%) to fully offset deferred tax liabilities of US$246m.  The remaining US$183m of losses represent an unrecognised deferred tax asset of US$73m.

A cash tax refund is receivable in Norway in respect of 78% of qualifying exploration and overhead spend. US$27m of tax credits are recorded for amounts receivable relating to the current period.  Norwegian deferred tax liabilities at 30 June of US$2m reflect timing differences on the carrying value of exploration assets where a tax refund has been claimed. 

Increases in the share price of CIL and subsequently VL have led to the recognition of a deferred tax liability reflecting the increase in value over-and-above the tax base costs.  A deferred tax liability of US$43m has been provided in the period.  US$35m was recycled from other comprehensive income following derecognition of the CIL shareholding and this is offset by a deferred tax credit of US$7m of recognition of VL shares at a lower market value.

The asset related tax credit relates to losses recognised as deferred tax assets to offset deferred tax liabilities arising on the final spend under the Catcher carry, recorded in development additions. UK deferred tax assets are recognised only to the extent that they offset liabilities and no net UK deferred tax asset or liability is recorded at the balance sheet date end.