Serica Energy Regulatory News (SQZ)

Serica Energy plc

("Serica" or the "Company")

Q2 2011 Results

London, 10 August 2011 - Serica Energy plc (TSX & AIM: SQZ), the oil and gas exploration and production company, today announces its financial results for the three and six months ending 30 June 2011. The results and associated Management Discussion and Analysis are included below and copies are available at www.serica-energy.com and www.sedar.com.

The following provides highlights for the second quarter ending 30 June 2011:

Operational:

·; Kambuna field gas production averaged 39.7 mmscfd (gross)

·; Kambuna field condensate production averaged 2,699 bpd (gross)

·; Gas sales price averaged US$6.20 per mscf and condensate averaged US$120.20 per bbl

·; Columbus Field Development Plan submitted

·; Agreement announced to appraise the Spaniards discovery in the UK North Sea

Corporate:

·; Agreement reached to sell the Company's Indonesian business excluding certain assets to Pace Petroleum for US$33 million as at 1 January 2011 with further contingent consideration of US$2 million

Financial:

·; Cash and cash equivalents as at 30 June 2011 of US$15.4 million with no debt

·; Loss before tax from continuing operations of US$2.63 million

·; Indonesian business shown as discontinued operations following decision to sell

·; Discontinued operations generated second quarter revenues of US$6.61 million with a gross profit of US$1.16 million

·; After fair market adjustment, discontinued operations generates loss of US$8.71 million

Outlook:

·; Columbus continues to move towards project sanction

·; Multi-well drilling programme planned for 2012

·; Efforts to increase this programme through farm out or acreage exchange

·; Key objective is to enlarge portfolio through acquisitions of complementary assets, sharing or exchange of acreage and new licences in UK and overseas

Tony Craven Walker, Chairman of Serica commented:

"Serica is in a positive cash position with production in Indonesia, a near term field development at late planning stage and several material undrilled exploration prospects. Although we still await completion of the transaction by GEMS/Pace the agreement to sell our Indonesian business is aimed at refocusing resources to enable us to exploit our unrealised potential through a drilling campaign starting in 2012.

We are also committed to enlarge our portfolio in order to increase opportunity, reduce risk and provide increased scale and diversity for the benefit of shareholders. We are aiming to pursue this objective through the acquisition of complementary assets in existing and new areas and opportunities to exchange and share licence interests with other companies as well as through application for new licences.

The current difficult economic environment and volatile markets are likely to provide challenges and uncertainty as we go forward but we believe that the steps we have been taking to refocus our efforts and strengthen our resources will place us in a good position to achieve these objectives."

10 August 2011

Enquiries:

The technical information contained in the announcement has been reviewed and approved by Peter Sadler, Business Development Director of Serica Energy plc. Peter Sadler is a qualified Petroleum Engineer (MSc Imperial College, London, 1982) and has been a member of the Society of Petroleum Engineers since 1981.

Notes to Editors

Serica Energy plc is an oil and gas exploration and production company based in London, England, and holds exploration and production licences in the UK offshore, onshore Spain, the Atlantic Margins of Ireland and Morocco and in Indonesia. The Company's producing and development assets are a 25% interest in the producing Kambuna field offshore Indonesia and a 50% stake in that part of the Columbus field lying in UK Central North Sea block 23/16f.

Forward Looking Statements

This disclosure contains certain forward looking statements that involve substantial known and unknown risks and uncertainties, some of which are beyond Serica Energy plc's control, including: the impact of general economic conditions where Serica Energy plc operates, industry conditions, changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced, increased competition, the lack of availability of qualified personnel or management, fluctuations in foreign exchange or interest rates, stock market volatility and market valuations of companies with respect to announced transactions and the final valuations thereof, and obtaining required approvals of regulatory authorities. Serica Energy plc's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward looking statements and, accordingly, no assurances can be given that any of the events anticipated by the forward looking statements will transpire or occur, or if any of them do so, what benefits, including the amount of proceeds, that Serica Energy plc will derive therefrom.

To receive Company news releases via email, please contact nick.elwes@collegehill.com and specify "Serica press releases" in the subject line.

MANAGEMENT'S DISCUSSION AND ANALYSIS

The following management's discussion and analysis ("MD&A") of the financial and operational results of Serica Energy plc ("Serica") and its subsidiaries (together the "Group") contains information up to and including 9 August 2011 and should be read in conjunction with the attached unaudited interim consolidated financial statements for the period ended 30 June 2011. The interim financial statements for the three and six months ended 30 June 2011 have been prepared by and are the responsibility of the Company's management. The interim financial statements for the six months ended 30 June 2011 and 2010 have been reviewed by the Company's independent auditors.

References to the "Company" include Serica and its subsidiaries where relevant. All figures are reported in US dollars ("US$") unless otherwise stated.

The results of Serica's operations detailed below in this MD&A, and in the financial statements, are presented in accordance with International Financial Reporting Standards ("IFRS").

MANAGEMENT OVERVIEW - QUARTER ENDED 30 JUNE 2011

Serica is an oil and gas company with exploration, development and production activities in the UK, Ireland, Spain, Morocco and Indonesia. The Company produces gas and gas condensate in Indonesia and holds additional gas and gas condensate reserves for development in the UK.

Main operational developments in quarter ended 30 June 2011

During the second quarter of 2011 the Company announced agreement to sell the balance of its Indonesian exploration and production assets to Pace Petroleum, submitted a Field Development Plan for the Columbus gas field to the UK Department of Energy and Climate Change ("DECC") for approval on behalf of its partners in the field and announced an agreement to drill a well to appraise the Spaniards discovery in UK North Sea Block 15/21a, believed to extend into Block 15/21g. This well is expected to be part of a multi-well UK drilling programme that the Company is planning for 2012.

These main second quarter activities are described in more detail below

Proposed sale of Indonesian properties

In November 2010 the Company announced a review of its holdings in Indonesia including its interest in the producing Kambuna gas field in North Sumatra.

After evaluating proposals from a number of companies, the Company announced on 30 June 2011 that it had accepted an offer from Pace Petroleum, a new company formed to invest in South East Asia oil and gas, under which Pace plans to acquire Serica's subsidiary group of companies which hold the Company's Indonesian business. The funding for this transaction is to be provided by a new resources fund being finalised by GEMS, an Asian Private Equity Group based in Hong Kong. Advice was received at the time of the announcement from GEMS that they expected completion of their fundraising in July and the transaction to complete expeditiously thereafter.

As of 8 August 2011 the Company has received updated advice from GEMS that the fundraising has not completed in accordance with this timetable but is anticipated to do so after a further short delay. In the light of current market conditions which introduce further uncertainty, and the possibility of the GEMS financing not completing in an acceptable time-frame, the Company is continuing to hold discussions with other parties who have made alternative proposals.

The proposed sale to Pace, which is subject to final approvals by both GEMS and Serica's Board, comprises the companies which hold the Company's 25% interest in the Kambuna field, its 30% interest in the Kutai exploration block offshore East Kalimantan and its 100% interest in the East Seruway block offshore North Sumatra. The agreed cash consideration, as at 1 January this year, is US$33 million adjusted for working capital plus a deferred payment of US$2 million, contingent on the outcome of the Kambuna #5 well planned for drilling later this year. The proposed sale excludes the value of certain oilfield equipment, which will be retained by Serica, and the value of VAT tax receipts in respect of past costs which will pass through to Serica as they are received.

As a result of the decision by the Company to dispose of its remaining Indonesian assets and the conditional sale agreed with Pace, the various assets and associated liabilities of the Company's Indonesian business form part of a disposal group and have been presented as held for sale in the Group Balance Sheet at 30 June 2011. The financial results of the Indonesian business disposal group are disclosed as discontinued operations and separate from the results of the retained business segments.

UK Columbus field

In June the Company, as operator, submitted the Columbus Field Development Plan to DECC for their approval on behalf of our partners in the field. Netherland Sewell & Associates estimate that the Columbus field contains some 79.5 bcf of gas and 4.9 mmbbls of condensate 2P reserves, together amounting to some 18.2 mmbbls of oil equivalent. The field extends from the Company's Block 23/16f to the south into Block 23/21 which contains the Lomond field and is operated by BG International Limited ("BG"). Bringing this valuable resource to development will be a major step for Serica.

Serica has been actively co-operating with BG in the front end engineering design studies for a new Bridge Linked Platform to handle production from the Columbus field. The construction and use of the Bridge Linked Platform forms the basis of the Field Development Plan agreed by the Columbus field partners, Endeavour Energy UK Limited, EOG Resources United Kingdom Limited, BG and SSE E&P UK Limited, and submitted to DECC. The Bridge Linked Platform is planned to be installed adjacent to the existing Lomond field platform and receive production from Columbus and other nearby fields for processing on the Lomond platform and onward transportation to the CATS and Forties pipeline systems.

Whilst the partners await DECC approval for the Columbus Field Development Plan discussions are continuing with BG to determine the relative interests of the 23/16f and 23/21 partners in the field and other items required to be agreed prior to project sanction. In view of the importance to the UK of the efficient development of new UK gas reserves it is hoped that these discussions will reach an expeditious conclusion enabling production to commence in 2014.

UK Drilling plans

Serica has several material undrilled prospects in its portfolio. These prospects have been subjected to in-depth evaluation by the Company during the second quarter with a view to a multi-well drilling programme in 2012. Wells are currently under review to test the Doyle prospect in Block 113/27c, to appraise the Spaniards discovery extending from Block 15/21a into Block 15/21g and to test a series of down-faulted oil prospects in northern North Sea Blocks 210/19a and 20a adjacent to the Otter oil field.

The Company holds material interests in each of these prospects. To maintain the appropriate portfolio balance the Company will be seeking partners for certain of these wells through farm-out but will also be seeking to increase its exploration drilling programme through exchange of interests in similarly attractive near-term drilling prospects.

At the end of the second quarter, Serica and its partners in Block 15/21g in the central North Sea, announced they had agreed terms to acquire a 70 per cent interest in a part of adjoining Block 15/21a through the cross-assignment of licence interests and the drilling of a well to appraise the Spaniards discovery. This well will be part of Serica's planned 2012 drilling programme.

Non-UK Drilling plans

The Company has material interests in a number of identified prospects lying in Irish offshore waters. These include the large undrilled Muckish prospect lying in the Rockall Basin, which shows strong characteristics similar to Shell's nearby Dooish gas-condensate discovery, and the Boyne and Liffey oil and gas prospects in the Slyne Basin where Serica's Bandon 27/4-1 well, drilled in 2009, discovered oil and proved that all the ingredients exist in the block for oil generation and trapping. In Morocco the Company is at the early stages of exploration but has already identified some large prospects in the deep water Tarfaya Basin, a basin which is geologically analogous to the oil producing salt basins of West Africa.

During the second quarter the Company continued to map these prospects to full delineation prior to commencing a campaign to identify new partners to share drilling costs. Since the start of the year the Company has also submitted applications for exploration licences in a number of new areas where it believes there is significant potential for material oil and gas discoveries.

Management changes during the quarter ended 30 June 2011

A number of executive changes were effected in the quarter. Paul Ellis, Chief Executive, reached normal retirement age on 10 April 2011 and, in accordance with his contract, retired from the Company on that date. With effect from that date, pending appointment of a successor, Tony Craven Walker is acting as Chairman and interim CEO. On 1 April, Peter Sadler was appointed Business Development Director to pursue acquisition opportunities for the Company and Mitch Flegg, who has been with Serica since 2006, was appointed Chief Operating Officer.

SUMMARY OF LICENCE HOLDINGS

The following provides a summary of licence interests in which activities took place during the second quarter.

United Kingdom

Central North Sea: Block 23/16f - Columbus field

Block 23/16f covers an area of approximately 52 square kilometres in the UK Central North Sea and contains the majority of the Columbus gas field. The gas in Columbus is rich in condensate and therefore requires processing before it can enter a gas transportation system. In an independent reserves report undertaken by Netherland, Sewell & Associates at the end of 2010, Serica's share of proved and probable reserves in the field is estimated to be 26.8 bcf of sales gas and 1.8 mmbbl of liquids, a net 6.3 mmboe to Serica. During the quarter ended 30 June 2011 Serica, on behalf of the partners in the Columbus field, submitted the Field Development Plan to DECC for approval. Serica has a 50% interest in Block 23/16f and is operator for the block.

Central North Sea: Block 15/21g - Spaniards Prospect

Block 15/21g, in which Serica has a 30% interest, lies immediately west of the Scott oilfield and contains a potentially significant extension to the existing Jurassic oil discovery well 15/21-38 in Block 15/21a, which flowed 2,660 bpd of 25° API oil from a good quality Jurassic-aged Upper Claymore sand. The Spaniards prospect is a stratigraphic trap and pressure interpretation suggests that the oil column in the discovery well may extend down-dip into Block 15/21g.

During the second quarter, the 15/21a and 15/21g groups concluded their discussions on plans to drill a joint well to test the prospect. On 30 June, the Block 15/21g partners, announced they had agreed terms to acquire a 70 per cent interest in a part of adjoining Block 15/21a. The area in Block 15/21a to be acquired includes the 15/21a-38z Spaniards/Gamma discovery. In consideration, the Block 15/21g group have agreed to assign to the Block 15/21a group a 30 per cent interest in Block 15/21g, and have agreed to fund the cost of the first well to appraise the Spaniards/Gamma discovery. It has also been agreed that a subsequent appraisal well, if deemed necessary and approved by the partnership, would be funded on promoted terms by the current Block 15/21a partners, after which funding for any further wells would be by equity share.

As a result of the agreement, which is subject to DECC approval, Serica will have a 21% interest in the amalgamated area covering the Spaniards prospect and will be required to contribute a 30% share of the cost of drilling the first well to appraise the discovery and a 17.14% share of the cost of drilling a follow-up well.

East Irish Sea: Blocks 113/26b and 113/27c - Doyle Prospect

Serica has a 65% interest in these blocks and work during the second quarter of 2011 has focussed on detailing Doyle, the Sherwood sand gas prospect lying in the north of Block 113/27c. Following this evaluation a decision will be made with partners on plans to drill the prospect.

Northern North Sea: Blocks 210/19a and 210/20a

These blocks, in which Serica has a 100% interest, are contiguous part blocks lying immediately adjacent to the Otter oilfield. A number of oil prospects have been provisionally identified on the blocks at Jurassic Brent Group and Home Sand levels. Two of the Brent Group prospects are down-faulted traps, an emerging and successful play in the northern North Sea, and the other is a conventional Brent fault block. The fourth prospect is in a Jurassic reservoir known as the Home Sand.

Serica is currently evaluating seismic data with a view to fully delineating the prospects with the intention of drilling the first well to test the prospects in 2012. Before drilling, Serica is likely to seek a partner.

Pending UK Licences

The Company expects to receive the award of further licences under the 26th Round of UK Offshore Licensing when environmental assessments, currently being undertaken by DECC, have been completed.

Ireland

Slyne Basin: Blocks 27/4, 27/5 (west) and 27/9 - Liffey & Boyne Prospects

These blocks cover an area of 611 square kilometres in the Slyne Basin off the west coast of Ireland. Serica holds a 50% interest and operates the licence.

The shallow Jurassic oil discovery made by Serica in 2009 in the Bandon exploration well 27/4-1 provides clear evidence of the presence of oil in this part of the Slyne Basin although the discovery itself was not commercial. Deeper Jurassic oil prospects of potentially commercial size are, however, evident at the Liffey and Boyne locations in addition to the separate gas prospects at those locations. The Company has acquired site survey data in preparation for a drilling programme to test these prospects and is currently seeking a farm-in partner.

Rockall Basin: Blocks 5/17, 5/18, 5/22, 5/23, 5/27, and 5/28 - Muckish Prospect

Serica holds a 100% working interest in six blocks covering a total area of 993 square kilometres in the north-eastern part of the Rockall Basin off the west coast of Ireland.

The Rockall Basin extends over 100,000 square kilometres in which only three exploration wells have been drilled to date. The basin is therefore regarded as very underexplored. Of these exploration wells, the 12/2-1 Dooish gas-condensate discovery, approximately nine kilometres to the south of the licence, encountered a 214 metre hydrocarbon column.

A large exploration prospect, Muckish, has been identified on the licence and evaluation of the data has increased confidence in the potential of the prospect, which covers an area of approximately 30 square kilometres in a water depth of 1,450 metres. Serica intends to find a partner to join in drilling a well on Muckish.

Spain

Abiego, Barbastro, Binéfar and Peraltilla Exploration Permits

The Company holds a 75% interest and operatorship in the Abiego, Barbastro, Binéfar and Peraltilla Exploration Permits onshore northern Spain. The Permits cover an area of approximately 1,100 square kilometres between the Ebro Basin and the Pyrenees. Several gas prospects have been identified by Serica and Serica is currently seeking a partner to enable it to commit to drill an exploration well.

Morocco

Sidi Moussa and Foum Draa Petroleum Agreements

Serica holds a 25% interest in the Sidi Moussa and adjacent Foum Draa Petroleum Agreements offshore Morocco. The blocks together cover a total area of approximately 12,700 square kilometres in the sparsely explored Tarfaya Basin and extend from the Moroccan coastline into water depths reaching a maximum of 2,000 metres.

Sidi Moussa and Foum Draa are covered by over 5,200 square kilometres of modern 3D seismic data and over 2,000 kilometres of 2D seismic data and work during the quarter focussed on interpretation of this data. A drill or drop decision is required to be made at the end of the initial phases of the Agreements. The initial phase of the Sidi Moussa area is due to end in November 2011 and that of Foum Draa is due to end in February 2012.

The Tarfaya Basin is geologically analogous to the oil producing salt basins of West Africa. Although evaluation of the seismic data is not yet complete, Serica has identified a number of significant prospects in the blocks. It is the intention to seek a partner before entering the drilling phase.

Indonesia

As noted above in the Management Overview, Serica's interests in Indonesia have been subject to a strategic review which is expected to result in a sale of the properties.

A summary of Serica's interests in Indonesia and operational developments in the second quarter is detailed below.

North Sumatra: Glagah Kambuna TAC - Kambuna Field

The Glagah Kambuna TAC, containing the producing Kambuna gas field, covers an area of approximately 380 square kilometres and lies offshore North Sumatra. Serica holds an interest of 25% in the TAC. An independent reserves report by RPS Energy, undertaken at the end of 2010, estimated gross remaining proved and probable reserves in the Kambuna field as 28.1 bcf of sales gas and 2.3 mmbbl of condensate, a total of 8.2 mmboe as at 1 January 2011.

The Kambuna gas is used for power generation to supply electricity to the city of Medan in North Sumatra and for industrial uses. During the second quarter of 2011 gross production from the field amounted to 3.6 bcf of sales gas and 246,000 bbls of condensate. The average gas sales price realised was US$6.2 per mcf with condensate realising an average price of US$120 per barrel. The highest price achieved during 2011 to date is US$126 per barrel, achieved in April.

A well is planned to be drilled from the Kambuna platform, Kambuna #5, during the second half of 2011 to exploit the gas bearing potential of a likely northern extension of the field. This activity plus the planned installation of gas compression is intended to support the productive capacity of the field.

North Sumatra: East Seruway PSC

Serica holds a 100% interest in the East Seruway Production Sharing Contract ("PSC") offshore North Sumatra, Indonesia. The PSC, which lies adjacent to the Glagah Kambuna TAC, covers an area of approximately 5,864 square kilometres and is largely unexplored.

Following completion of the acquisition of 2,100 line kilometres of 2D seismic data in the PSC in 2010 the Company has identified a number of leads which will require further delineation before making a drilling decision. The Company will need the consent of both the Indonesian authorities and the semi-autonomous province of Aceh in order to undertake work in certain parts of the PSC.

East Kalimantan: Kutai PSC

Serica is the operator of the Kutai PSC and holds a 30% interest. The PSC is divided into five blocks located in the Mahakam River delta both onshore and offshore East Kalimantan.

The Company drilled two wells, Marindan and Dambus, in 2010. Both wells encountered hydrocarbons but in insufficient quantities to support standalone development. In the light of the Dambus result other prospects and leads in the area around the Dambus well are under review. Gas discovered at Dambus would reduce the threshold volume required for the development of any further resources that may be discovered in the immediate area.

FORWARD PROSPECTS

The Company is in a positive cash position with a portfolio of properties including a near-term field development and material exploration prospects lying in several different geological basins. The Company has the technical and proven operating skills to exploit these prospects and plans to commence a drilling programme in 2012 to establish their potential.

It is a key objective for the Company to enlarge this portfolio through applications for new licences, exchange and sharing of licence interests and acquisition of complementary assets to reduce risk and give it increased scale and diversity.

The agreement to dispose of Serica's properties in Indonesia is part of this strategy. Successful completion of the transaction will enable the Company to release and refocus resources for investment in the Company's existing acreage and in new areas where the Company sees greater growth opportunity.

FINANCIAL REVIEW

A detailed review of the Q2 2011 results of operations and other financial information is set out below.

As a result of the decision by the Company to dispose of its remaining Indonesian assets and the conditional sale agreed with Pace, the various assets and associated liabilities of the Company's Indonesian business form part of a disposal group and have been presented as held for sale in the Group Balance Sheet at 30 June 2011. The financial results of the Indonesian business disposal group are disclosed as discontinued operations and separate from the results of the retained business segments.

Results of Operations

Continuing operations

The Company generated a loss before tax from continuing operations of US$2.6 million for the three months ended 30 June 2011 ("Q2 2011") compared to a loss before tax of US$3.4 million for Q2 2010.

Pre-licence costs include direct cost and allocated general administrative cost incurred on oil and gas interests prior to the award of licences, concessions or exploration rights. The expense of US$0.6 million for Q2 2011 was at a similar level to the Q2 2010 charge. Significant work was undertaken in Q2 2011 in new areas of focus in the Western Hemisphere and the UK. The Q2 2010 expense primarily related to the 26th Licensing Round in the UK. In 2010 the Company was awarded interests in two UK blocks but is still awaiting the outcome of certain other applications from the 26th Round.

There were no significant asset write offs in Q2 2011 or Q2 2010. Asset write offs in Q4 2010 of US$3.7 million primarily included the E&E asset costs of the Oates prospect in the UK North Sea (US$3.5 million). The Management's decision to write off the costs of Oates followed the unsuccessful well and the absence of any further drilling plans for the block. Other Q4 2010 write offs included costs from relinquished licences.

Administrative expenses of US$1.5 million for Q2 2011 were unchanged from the same period last year. The Company continues to manage carefully its financial resources.

The impact of foreign exchange was not significant in Q2 2011 or Q2 2010.

Share-based payment costs of US$0.2 million in Q2 2011 reflected share options granted and compared with US$0.2 million for Q2 2010.

Negligible depreciation charges in all periods represent office equipment and fixtures and fittings.

Finance revenue comprising bank deposit interest income has been negligible in all periods during 2010 and 2011 to date.

Finance costs consist of interest payable, arrangement costs spread over the term of the bank loan facility, and other financing fees. Finance costs of US$0.2 million in Q2 2011 have fallen significantly from US$1.0 million in Q2 2010. The arrangement costs associated with the November 2009 financing were fully amortised during Q1 2011 following the loan repayment in February 2011. Ongoing finance costs currently only consist of unutilised facility fees.

The net loss per share from continuing operations of US$0.01 for Q2 2011 compares to a net loss per share of US$0.02 for Q2 2010.

Discontinued operations

The results of discontinued operations below are those generated from Serica's South East Asia operations which are recognised in a disposal group as at 30 June 2011.

Serica's Indonesian operations generated a gross profit of US$1.2 million in Q2 2011 (Q2 2010: US$3.1 million) from its 25% interest in the Kambuna Field.

The Company currently generates all its sales revenue from the Kambuna field in Indonesia. Revenue is recognised on an entitlement basis for the Company's net working field interest. Entitlement revenues are higher in those periods where the full capped amount of cost recovery entitlement is eligible to be claimed out of gross revenue. In Q2 2011, the cycle of eligible cost recovery was such that the full capped amount of cost recovery could not be claimed by the contractors, therefore giving lower contractor entitlement revenues and an increased government share of gross revenue. This has reduced Serica's reported entitlement revenues as a proportion of gross sales volumes in Q2 2011 compared to earlier periods. Unclaimed cost recovery amounts are carried forward to future periods.

In Q2 2011, gross Kambuna field gas production averaged 39.7 mmscf per day (Q2 2010 29.2 mmscf per day) together with average condensate production of 2,699 barrels per day (Q2 2010 2,666 barrels per day). The Q2 2011 gas production was sold at prices averaging US$6.20 per mscf (Q2 2010 US$5.48 per mscf) and generated US$3.9 million (Q2 2010 US$3.5 million) of revenue net to Serica. Condensate production is stored and sold when lifted at a price referenced to the Indonesia Attaka official monthly crude oil price. Liftings in the period earned US$2.7 million (Q2 2010 US$3.0 million) of revenue net to Serica at an average price of US$120.2 per barrel (Q2 2010 US$75.9 per barrel).

Cost of sales were driven by production from the Kambuna field and totalled US$5.5 million in Q2 2011 (Q2 2010: US$3.5 million). The most significant components of the total charge were non cash depletion of US$3.8 million (Q2 2010: US$1.8 million) and operating costs of US$1.7 million (Q2 2010: US$1.8 million). Depletion charges per boe increased significantly for Q4 2010, Q1 and Q2 2011 as the result of the 2010 year end reduction in estimated Kambuna field reserves.

The Q4 2010 US$11.8 million pre-tax impairment related to the Kambuna field and resulted from the year end reduction in estimated reserves. The impairment was recorded against oil and gas property, plant and equipment (US$11.7 million) and goodwill (US$0.1 million).

Minor asset write offs in Q2 2011 of US$0.2 million were in respect of the Kutai PSC in Indonesia. There were no asset write offs in Q2 2010. Asset write offs in Q4 2010 of US$25.7 million largely included E&E and other asset expenses from the Kutai PSC in Indonesia (US$25.1 million). The Management's decision to write off Kutai costs followed the impairment of the Kambuna field, whose reserves had previously covered the carrying cost of the Company's SE Asia assets.

Under IFRS 5, the assets and associated liabilities of the Indonesian disposal group have been reclassified at 30 June 2010. A fair value remeasurement exercise has been performed to measure the disposal group at the lower of its carrying amount and fair value less costs to sell. This remeasurement has generated a loss of US$8.7 million which is recognised in the results of discontinued operations. The write down of underlying assets has been apportioned in accordance with IFRS 5 on a pro rata basis to the non-current assets.

The Q2 2011 taxation charge of US$0.2 million (Q2 2010: US$1.0 million) comprised a current tax charge of US$1.6 million and a deferred tax credit of US$1.4 million.

The second quarter 2011 loss includes a loss of US$8.7 million recognised on the re-measurement to fair value of the Indonesian disposal group as at 30 June 2011.

The fourth quarter 2010 loss includes asset write offs of US$29.4 million attributed to the Kutai and Oates E&E assets and an impairment charge of US$11.8 against the Kambuna development and production asset.

The fourth quarter 2009 profit includes a profit of US$26.9 million generated on the disposal of a 25% interest in the Kambuna field, Indonesia and certain E&E asset interests in South East Asia.

The third quarter 2009 result includes first revenue streams from the Kambuna field.

Working Capital, Liquidity and Capital Resources

Current Assets and Liabilities

An extract of the balance sheet detailing current assets and liabilities is provided below:

At 30 June 2011, the Company had net current assets from continuing operations of US$17.0 million which comprised current assets of US$21.3 million less current liabilities of US$4.3 million, giving an overall decrease in working capital of US$4.5 million in the three month period.

Inventories decreased from US$2.8 million to US$1.6 million over the Q2 2011 period following the reclassification to 'assets held for sale' of stocks attached to the Indonesian joint venture interests. The balance as at 30 June 2011 relates to retained items of oilfield equipment.

Trade and other receivables at 30 June 2011 included advance payments on ongoing operations, recoverable amounts from partners in joint venture operations in the UK and Indonesia, sundry UK working capital balances, and prepayments. Trade and other receivables associated with Indonesian operations, including US$3.1 million of trade debtors from gas and condensate sales in May and June are now classified within 'assets held for sale'.

Financial assets at 30 June 2011 represented US$0.5 million of short term restricted cash deposits.

Cash and cash equivalents decreased from US$22.0 million to US$15.4 million in the quarter. In April 2011, the Company repaid significant liabilities outstanding from the Kutai exploration drilling programme including outstanding rig creditors, and also settled the full amounts of current Indonesian tax that had accrued since the start of field production in August 2009 to date. During Q2 2011 the Company generated US$6.6 million of revenues from the Kambuna field but also incurred ongoing field operating and capital costs. Other costs included new venture exploration work across the portfolio in the UK, Ireland and new areas of focus, Columbus Field Development Plan expense together with ongoing administrative costs and corporate activity. Cash balances held in Indonesian operations are no longer classified in cash and cash equivalents.

Trade and other payables at 30 June 2011 include trade creditors and accruals from ongoing operations on the Columbus field development, the UK, Ireland and Morocco exploration programmes, payables for administrative expenses and other corporate costs.

The current tax creditor of US$2.1 million at 31 March 2011 arose in respect of Indonesian operations and was settled in April. Current Indonesian tax liabilities are now classified as 'liabilities associated with assets held for sale'.

Financial liabilities at 31 December 2010 comprise drawings under the senior debt facility and are disclosed net of the unamortised portion of allocated issue costs. The balance was classified as short-term and was fully repaid in February 2011.

Assets held for sale and associated liabilities

The assets and liabilities recorded as at 30 June 2011 in respect of South East Asia interests being sold are now classified as part of a disposal group held for sale. These amounts stated in the balance sheet as at 30 June 2011 have been written down to the estimated fair value less costs to sell of the disposal group. The write down of underlying assets has been apportioned in accordance with IFRS 5 on a pro rata basis to the non-current assets.

Assets held for sale

Exploration and evaluation assets ("E&E assets") represent capitalised costs incurred to date on the East Seruway PSC.

Property, plant and equipment chiefly comprise the net book amount of the capital expenditure on the Company's interest in the Kambuna field.

Long-term other receivables are represented by value added tax ("VAT") on Indonesian capital spend which will be recovered from future production.

Other working capital assets are all associated with South East Asia operations.

Liabilities associated with assets held for sale

Trade and other payables at 30 June 2011 chiefly include creditors and accruals from the Kambuna field operations. Significant liabilities from the Q4 2010 Kutai offshore drilling programme, including the final drilling rig costs were settled during Q2 2011. Other liabilities include sundry creditors and accruals from the ongoing Indonesian exploration programmes.

The current taxation creditor of US$0.6 million arises in respect of Kambuna operations.

Provisions of US$1.7 million were in respect of Kambuna field decommissioning payments.

Long-Term Assets and Liabilities

An extract of the balance sheet detailing long-term assets and liabilities is provided below:

During Q2 2011, total investments in petroleum and natural gas properties represented by exploration and evaluation assets ("E&E assets") decreased from US$70.7 million to US$65.0 million. The overall decrease was largely due to the reclassification of Indonesia E&E asset costs on the East Seruway PSC (US$6.7 million) as 'assets held for sale' as at 30 June 2011. US$0.4 million of additions were incurred on the East Seruway PSC in Q2 2011 prior to the reclassification.

Also during Q2 2011, US$0.6 million of additions were incurred in respect of continuing operations. In the UK & Western Europe, US$0.2 million was incurred on the Columbus FDP and US$0.2 million on other UK and Ireland exploration work and G&A. US$0.2 million was incurred on the Morocco interests.

The property, plant and equipment balance of US$0.6 million at 30 June 2011 (31 December 2010: US$0.8 million) represents office fixtures and fittings and computer equipment.

In previous periods, property, plant and equipment chiefly comprised the net book amount of the capital expenditure on the Company's interest in the Kambuna development. These amounts were reclassified as 'assets held for sale' as at 30 June 2011. During Q2 2011, the Company's investment in Kambuna decreased from US$31.6 million to US$28.5 million. This US$3.1 million decrease comprised depletion charges of US$3.8 million arising from the production of gas and condensate, partially offset by US$0.7 million of capital additions in the period.

Goodwill, representing the difference between the price paid on acquisitions and the fair value applied to individual assets, was impaired following the 2010 year end reduction in estimated Kambuna reserves and fully written off in Q4 2010.

Financial assets at 30 June 2011 represented US$0.7 million of restricted cash deposits.

Long-term other receivables are represented by value added tax ("VAT") on Indonesian capital spend which will be recovered from future production. These assets are now classified as 'assets held for sale'.

Financial liabilities represented by drawings under the senior secured debt facility are disclosed net of the unamortised portion of allocated issue costs.

Provisions of US$1.7 million at 31 March 2011 and 31 December 2010 were in respect of Kambuna field decommissioning payments in Indonesia. This provision is now classified as 'liabilities associated with assets held for sale'.

The deferred income tax liabilities arise in respect of the Company's Kambuna asset interest in Indonesia. These liabilities have now been fully released in the period.

Shareholders' Equity

An extract of the balance sheet detailing shareholders' equity is provided below:

Total share capital includes the total net proceeds, both nominal value and any premium, on the issue of equity capital.

Other reserves mainly include amounts credited in respect of cumulative share-based payment charges. The increase in other reserves from US$18.7 million to US$19.0 million reflects a credit to equity in respect of share-based payment charges in Q2 2011.

Asset values and Impairment

At 30 June 2011 Serica's market capitalisation stood at US$68 million (£42 million), based upon a share price of £0.24, which was exceeded by the net book value at that date of US$117 million (£72 million). Management conducted a thorough review of the carrying value of its assets and determined that no further write-downs were required beyond those already disclosed above.

Capital Resources

Available financing resources and debt facility

Serica's prime focus has been to deliver value through exploration success. To-date this has given rise to the Kambuna gas field development in Indonesia and the Columbus gas field in the UK North Sea, for which development plans are being formulated.

Typically exploration activities are equity financed whilst field development costs are principally debt financed. In the current business environment, access to new equity and debt remains uncertain. Consequently, the Company has given priority to the careful management of existing financial resources.

In November 2009 the Company replaced its US$100 million debt facility with a new three-year facility for an equal amount. The new facility, which was arranged with J.P.Morgan plc, Bank of Scotland plc and Natixis as Mandated Lead Arrangers, was principally to refinance the Company's outstanding borrowings on the Kambuna field. It was also put in place to finance the appraisal and development of the Columbus field and for general corporate purposes.

Following the debt repayments in 2010, management reduced its debt facility to US$50 million total capacity so as to restrict ongoing facility costs. The ability to draw under the facility for development is determined both by the achievement of milestones on the relevant project and also by the availability calculated under a projection model. The Company's debt facility was fully repaid in February 2011.

At 30 June 2011, the Company held cash and cash equivalents of US$15.4 million and US$1.2 million of short and long term restricted cash in continuing operations. Overall, the current cash balances held, the crystallisation of value from Indonesia either through disposal or the revenues from a retained 25% Kambuna interest, and the control that the Company can exert over the timing and cost of its exploration programmes both through operatorship and through farm-outs leave it well placed to manage its commitments.

Summary of contractual obligations

The following table summarises the Company's contractual obligations as at 30 June 2011;

All bank debt was repaid in February 2011.

Other long term obligations relate to decommissioning payments in Indonesia.

Lease commitments

At 30 June 2011, Serica had no capital lease obligations. At that date, the Company had commitments to future minimum payments under operating leases in respect of rental office premises and office equipment for each of the following period/years as follows:

Capital expenditure commitments, obligations and plans

As at 30 June 2011, the Company's share of expected outstanding capital costs in respect of its 25% interest on the Kambuna project totalled approximately US$4.4 million. These expected costs primarily comprise budgeted costs for the proposed Kambuna North well.

In addition, the Company also has obligations to carry out defined work programmes on its oil and gas properties, under the terms of the award of rights to these properties, over the next two period/years as follows:

Period ending 31 December 2011 US$ 1,500,000

Year ending 31 December 2012 US$ nil

These obligations reflect the Company's share of the defined work programmes and were not formally contracted at 30 June 2011. The Company is not obliged to meet other joint venture partner shares of these programmes. The most significant 2011 obligations are in respect of the Kutai PSC in Indonesia. Significant drilling commitment obligations in respect of the East Seruway PSC were previously classified as falling in the period ending 31 December 2011. It has been confirmed that the Company will need the consent of both the Indonesian authorities and the semi-autonomous province of Aceh in order to undertake this work, and the expected timeframe of the obligation has now slipped beyond 2012. Other less material minimum obligations include G&G, seismic work and ongoing licence fees in the UK and Indonesia.

Off-Balance Sheet Arrangements

The Company has not entered into any off-balance sheet transactions or arrangements.

Critical Accounting Estimates

The Company's significant accounting policies are detailed in note 2 to the attached interim financial statements. International Financial Reporting Standards have been adopted. The costs of exploring for and developing petroleum and natural gas reserves are capitalised and the capitalisation and any write off of E&E assets, or depletion of producing assets necessarily involve certain judgments with regard to whether the asset will ultimately prove to be recoverable. Key sources of estimation uncertainty that impact the Company relate to assessment of commercial reserves and the impairment of the Company's assets. Oil and gas properties are subject to periodic review for impairment whilst goodwill is reviewed at least annually. Impairment considerations necessarily involve certain judgements as to whether E&E assets will lead to commercial discoveries and whether future field revenues will be sufficient to cover capitalised costs. Recoverable amounts can be determined based upon risked potential, or where relevant, discovered oil and gas reserves. In each case, recoverable amount calculations are based upon estimations and management assumptions about future outcomes, product prices and performance. Management is required to assess the level of the Group's commercial reserves together with the future expenditures to access those reserves, which are utilised in determining the amortisation and depletion charge for the period and assessing whether any impairment charge is required.

Financial Instruments

The Group's financial instruments comprise cash and cash equivalents, bank loans and borrowings, accounts payable and accounts receivable. It is management's opinion that the Group is not exposed to significant interest or credit or currency risks arising from its financial instruments other than as discussed below:

Serica has exposure to interest rate fluctuations on its cash deposits and its bank loans; given the level of expenditure plans over 2011/12 this is managed in the short-term through selecting treasury deposit periods of one to three months. Treasury counterparty credit risks are mitigated through spreading the placement of funds over a range of institutions each carrying acceptable published credit ratings to minimise counterparty risk.

Where Serica operates joint ventures on behalf of partners it seeks to recover the appropriate share of costs from these third parties. The majority of partners in these ventures are well established oil and gas companies. In the event of non payment, operating agreements typically provide recourse through increased venture shares.

Serica retains certain cash holdings and other financial instruments relating to its operations, limited to the levels necessary to support those operations. The US$ reporting currency value of these may fluctuate from time to time causing reported foreign exchange gains and losses. Serica maintains a broad strategy of matching the currency of funds held on deposit with the expected expenditures in those currencies. Management believes that this mitigates much of any actual potential currency risk from financial instruments. Loan funding is available in US Dollars and Pounds Sterling and is drawn in the currency required.

It is management's opinion that the fair value of its financial instruments approximate to their carrying values, unless otherwise noted.

Share Options

As at 30 June 2011, the following director and employee share options were outstanding:

In April 2011, 200,000 share options were granted to an executive director with an exercise cost of £0.31 and an expiry date of 4 April 2021. The exercise of the options is subject to certain performance criteria. The options granted in April 2011 cannot be exercised until three years from the date of grant.

103,000 options with an expiry date of November 2015 were cancelled in July 2011.

Outstanding Share Capital

As at 9 August 2011, the Company had 176,660,311 ordinary shares issued and outstanding.

Business Risk and Uncertainties

Serica, like all companies in the oil and gas industry, operates in an environment subject to inherent risks. Many of these risks are beyond the ability of a company to control, particularly those associated with the exploring for and developing of economic quantities of hydrocarbons. Principal risks can be classified into four main categories: operational, commercial, regulatory and financial.

Operational risks include production interruptions, well or reservoir performance, spillage and pollution, drilling complications, delays and cost over-run on major projects, well blow-outs, failure to encounter hydrocarbons, construction risks, equipment failure and accidents. Commercial risks include access to markets, access to infrastructure, volatile commodity prices and counterparty risks. Regulatory risks include governmental regulations, licence compliance and environmental risks. Financial risks include access to equity funding and credit.

In addition to the principal risks and uncertainties described herein, the Company is subject to a number of other risk factors generally, a description of which is set out in the Company's latest Annual Information Form available on www.sedar.com.

Nature and Continuance of Operations

The principal activity of the Company is to identify, acquire and subsequently exploit oil and gas reserves. Its current activities are located primarily in Western Europe, North Africa and Indonesia.

The Company's financial statements have been prepared with the assumption that the Company will be able to realise its assets and discharge its liabilities in the normal course of business rather than through a process of forced liquidation. During the three month period ended 30 June 2011 the Company generated a loss of US$2.6 million from continuing operations. At 30 June 2011 the Company had US$15.4 million of net cash in continuing operations.

The Company intends to utilise its existing cash balances and future operating cash inflows, together with the currently available portion of the US$50 million senior secured debt facility, to fund the immediate needs of its investment programme and ongoing operations. Further details of the Company's financial resources and debt facility are given above in the Financial Review in this MD&A.

Key Performance Indicators ("KPIs")

The Company's main business is the acquisition of interests in prospective exploration acreage, the discovery of hydrocarbons in commercial quantities and the crystallisation of value whether through production or disposal of reserves. The Company tracks its non-financial performance through the accumulation of licence interests in proven and prospective hydrocarbon producing regions, the level of success in encountering hydrocarbons and the development of production facilities. In parallel, the Company tracks its financial performance through management of expenditures within resources available, the cost-effective exploitation of reserves and the crystallisation of value at the optimum point.

Additional Information

Additional information relating to Serica can be found on the Company's website at www.serica-energy.com and on SEDAR at www.sedar.com

Approved on Behalf of the Board

10 August 2011

Forward Looking Statements

This disclosure contains certain forward looking statements that involve substantial known and unknown risks and uncertainties, some of which are beyond Serica Energy plc's control, including: the impact of general economic conditions where Serica Energy plc operates, industry conditions, changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced, increased competition, the lack of availability of qualified personnel or management, fluctuations in foreign exchange or interest rates, stock market volatility and market valuations of companies with respect to announced transactions and the final valuations thereof, and obtaining required approvals of regulatory authorities. Serica Energy plc's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward looking statements and, accordingly, no assurances can be given that any of the events anticipated by the forward looking statements will transpire or occur, or if any of them do so, what benefits, including the amount of proceeds, that Serica Energy plc will derive therefrom.

Serica Energy plc

Group Income Statement

For the period ended 30 June

Total Statement of Comprehensive Income

There are no other comprehensive income items other than those passing through the income statement.

Serica Energy plc

Consolidated Balance Sheet

Serica Energy plc

Statement of Changes in Equity

For the period ended 30 June 2011

For the year ended 31 December 2010

Serica Energy plc

Consolidated Cash Flow Statement

For the period ended 30 June