Iraq’s Energy Sector: Roadmap to a Brighter Future

Iraq, one of the world’s biggest energy producers, can address its current electricity shortfall and growing power needs through immediate action to relieve pressure on the system, according to an in-depth report published Thursday by the International Energy Agency.

It also provides a medium-term strategy that makes the best use of the country’s abundant oil and natural gas resources and solar potential.

Despite the extraordinary challenges of war in recent years, Iraq has made impressive gains, nearly doubling the country’s oil production over the past decade. But the turmoil has also undermined the country’s ability to maintain and invest in its power infrastructure.

The new IEA report, Iraq’s Energy Sector: A Roadmap to a Brighter Future, maps out immediate practical actions and medium-term measures to tackle the most pressing problems in Iraq’s electricity sector.

The analysis finds Iraq has huge potential to cut its electricity network losses, which are among the highest in the world. Reducing these losses by half would help dramatically improve the efficiency of grid supply, effectively increasing available capacity by one-third.

The report also takes a detailed look at the country’s oil and gas sector. It projects that Iraq’s oil production will grow by 1.3 million barrels a day by 2030, accounting for the third-largest increase globally over the period, and soon becoming the world’s fourth-largest oil producer behind the United States, Saudi Arabia and Russia.

The report also notes that more gas can be captured and put to use in efficient power plants. Today, 16 billion cubic meters of gas are flared each year, more than enough to replace Iraq’s current imports.

Dr Fatih Birol, the IEA’s Executive Director met, with Iraqi President Barham Salih on Wednesday in Baghdad, and presented the study’s findings and recommendations. He then met with Prime Minister Adil Abdul-Mahdi to discuss ways forward for the electricity sector, including making best use of Iraq’s significant natural gas and solar resources.

On Thursday, Dr Birol will discuss the report at a press conference with Thamir Ghadhban, the Deputy Prime Minister for Energy and Minister of Oil, and Luay Al-Khatteeb, the Minister of Electricity.

The IEA has worked closely with the Iraqi Ministries of Oil and Electricity to produce the report, and would like to thank the ministers and their staff for their cooperation with this study.

“Operating under extremely challenging circumstances, Iraq has done a remarkable job expanding its oil industry,” said Dr Birol. “Today’s urgent issue is to address the national power sector as the summer heatwave approaches by improving grid maintenance, boosting electricity production with larger mobile generators, and incentivising upgrades of power plants. The IEA is pleased to recommend immediate practical actions for the benefit of the entire Iraqi people, and provide a roadmap for a sustainable power system in the medium term.”

Iraq’s electricity demand is set to double between now and 2030, and its shortfall in electricity supply will widen, as the country’s population grows by more than 1 million people each year.

Without changes to the current structure of electricity supply and improvements to the network, domestic generation, imports and neighbourhood generation would need to double by 2030, for a total supply of over 250 TWh. However, there are many opportunities to improve on this outcome through measures such as investing in transmission and distribution to cut network losses.

Promoting the more efficient use of electricity, including by introducing more progressive tariffs, would play an important role in ensuring that the growth in demand during the summer peak does not continue to outpace supply.

Iraq also needs to take advantage of its abundant renewable energy potential.  The analysis shows that expanding the share of solar PV and wind to 30% of electricity supply by 2030 would bring benefits both to the Iraqi consumer, in the form of reduced electricity bills, and to the environment.

Reducing network losses and moving towards an electricity mix where renewables play a more prominent role would free up 9 billion cubic meters of gas for other uses in 2030, plus 450 kb/d of oil for export.

“In addition to oil, Iraq is blessed with some of the richest solar and gas resources in the world but it is yet to take advantage of them,” Dr Birol said. “Turning that potential into fuel for its own economy and for export would help bring about a more sustainable, reliable and affordable energy future.”

The report is the second in-depth study of Iraq’s energy sector following the publication of the Iraq Energy Outlook in 2012.

Download the report here.

(Source: IEA)

Oil Production to Increase at Gharaf

By John Lee.

Japex is reportedly planning to increase production at the Gharaf oil field from around 90,000 barrels of oil per day (bpd) currently to 230,000 bpd by the end of 2020.

S&P Global Platts quotes Japex director Michiro Yamashita as saying that the company has allocated capital expenditure of $460 million for the project in fiscal 2019-20 (April-March).

(Source: S&P Global Platts)

Peshkabir has generated $1bn, 4x Total Spend

DNO, as operator of the Tawke field in Iraqi Kurdistan, has today issued an update on licence activity.

Gross production from the Tawke licence, containing the Tawke and Peshkabir fields, averaged 126,759 bopd during the first quarter of 2019.

Tawke production currently averages c.73,000 bopd, and Peshkabir c.54,000 bopd. There is an active 2019 drilling campaign underway at the Tawke and Peshkabir fields, with a total of up to four Peshkabir wells and up to 14 Tawke wells.

The Peshkabir-9 well was completed and placed on production during the first quarter. The Peshkabir-10 well was spud in February and will come onstream shortly. The Peshkabir-11 well will spud later this month. Peshkabir production averaged 53,830 bopd during the first quarter.

Peshkabir has now generated $1 billion in gross revenue, or four times the total spend to date.

At the Tawke field, the Tawke-52 Cretaceous well was completed and placed on production during the quarter. The Tawke-54 Cretaceous well was spud in February and came onstream in mid-April, and the Tawke-55 Cretaceous well spud in April. Tawke field production averaged 72,929 bopd during the first quarter.

(Source: Genel Energy)

West Qurna-2 hits 400,000 bpd

Cumulative production at the West Qurna-2 field has reached 100 million tons of oil as part of successful implementation of Phase 1 of the project.

With 184 wells drilled at the field, the average daily production rate is 400,000 barrels.

Operator Lukoil said in a statement that, to manage the field’s production, it uses “the intelligent field concept which allows to control and adjust where necessary the production indicators in real-time.”

In 2018, the company started Phase 2 of the field’s development which envisages  growth in daily production to 480,000 barrels in 2020 and to a plateau of 800,000 barrels per day in 2025.

In January 2019, the drilling of 28 wells began on well pad #4. As of today, contracts have been signed to drill 57 production wells, including 54 at the Mishrif and 3 at the Yamama formations.

(Source: Lukoil)

New Oil Well Enters Production at Taq Taq

By John Lee.

Share in Genel Energy closed Thursday up 2.75% after the company announced an update on activity at the Taq Taq field (Genel 44% working interest), as testing of the TT-20z well has now been completed.

In a statement, the company said the well has entered production at an initial rate of 2,000 bopd with a 24/64″ choke, and this figure is expected to rise. With the inclusion of this production, gross production from the Taq Taq field is currently c.15,500 bopd, with Genel’s overall net production now c.39,000 bopd.

The well flowed oil from all three zones tested, with a maximum combined flow rate of c.4,000 bopd with a 40/64″ choke.

The statement added:

“The well is further proof of the remaining potential on the flanks of Taq Taq field. With Taq Taq wells an attractive capital allocation option, the rig has moved to drill the TT-33 well, on the southern flank of the field. The well was spudded on 25 March, and is expected to take 90 days to complete.”

(Source: Genel Energy)

Gazprom Neft expands Oil Production at Sarqala

Russia’s Gazprom Neft has commissioned a third production well at its Sarqala field in the Kurdistan Region of Iraq (KRI)

Potential production at this new well is estimated at 12,000 barrels per day. Cumulative daily oil production at the field following the commissioning of the Sarqala-3 well has increased by 25 percent reaching 35,000 barrels.

The well runs to a total depth of 3,291 metres, with drilling having been undertaken under the challenging geological conditions of the Sarqala field — anomalously high pressure and reservoir temperature having demanded the use of a selection of 11 technological solutions. The construction of the Sarqala-3 well has, as a result, involved the use of large-diameter casing pipes with ultra-strong thread connections, weighted drilling mud for bottom-hole flushing, and cement incorporating mineral-based and iron-oxide additives.

Drilling the well has involved an international team, with members from 20 countries. The project was implemented by Gazprom Neft Middle East, with technical support from the Gazprom Neft Science and Technology Centre.

Vadim Yakovlev, First Deputy CEO, Gazprom Neft, commented:

“The Middle East remains an area of strategic interest to Gazprom Neft, being a region with a rich resource base, and a demonstrable willingness to allow access to investors. Experience in implementing projects from scratch — both in exploration and production — is important to us. We are continuing to evaluate opportunities for the further development of our business in the Middle East — independently and in partnership with other companies — both using the synergies offered by existing project infrastructure, as well as at other assets.”

(Source: Gazprom Neft)

DNO Reports Record Revenues

DNO ASA, the Norwegian oil and gas operator, today announced 2018 net profit of USD 354 million on revenues of USD 829 million, the highest annual revenues in the Company’s 47-year history. Cash flow from operations increased 40 percent to USD 472 million in 2018, of which USD 334 million represented free cash flow.

Operated production averaged 117,600 barrels of oil equivalent per day (boepd) including 81,700 boepd on a Company Working Interest (CWI) basis, up from 113,500 boepd and 73,700 boepd, respectively, during 2017. January 2019 operated production averaged 128,000 barrels of oil per day (bopd) or 90,000 bopd on a CWI basis.

The Company stepped up its operational spend in 2018 to nearly USD 300 million to support the fast-track development of the Peshkabir field in the Kurdistan region of Iraq and the ongoing drilling program at the Tawke field within the same license.

Spending levels in 2019 are projected to rise more than 40 percent from 2018 levels to an estimated USD 420 million. DNO’s 2019 drilling program includes up to 20 exploration and production wells in Kurdistan, including up to 14 wells at the Tawke field, four at Peshkabir and two at the Baeshiqa license. Another five wells are planned in Norway on DNO’s licenses.

In Kurdistan, two recently completed wells, Peshkabir-9 and Tawke-52, will be placed on production in February. Testing of the first Baeshiqa exploration well targeting the Cretaceous reservoir has been delayed by extensive rainfall but is also expected to commence this month.

Already the leading international oil company in Kurdistan, with a 75 percent operating interest in fields contributing a third of the region’s total exports, the Company is now firmly establishing itself in Norway as it completes the takeover of Faroe Petroleum plc. With 90 licenses, of which 22 are operated, DNO will leapfrog to the ranks of the top five companies in total licenses held in Norway.

“The Faroe transaction transforms DNO into a more diversified company with a strong, second leg,” said DNO’s Executive Chairman Bijan Mossavar-Rahmani. “This represents not a pivot away from Kurdistan but a pivot to Norway,” he added. “We are now well positioned in two areas in which we have a comparative, even competitive, advantage.”

The combination places DNO among the top three European-listed independent oil and gas companies in production and reserves.

DNO has acquired more than 96 percent of Faroe shares and initiated the compulsory acquisition of the remaining shares. The integration of the Faroe and DNO organizations is well underway; the new combined entity has over 1,100 employees and offices in Oslo, Stavanger, Erbil, Dubai, London, Aberdeen and Great Yarmouth.

The Company will release pro-forma financials and 2019 investment programs and budgets for the combined entity in February and March.

Separately, DNO’s Board of Directors have approved a dividend payment of NOK 0.20 per share to be made on or about 27 March 2019 to all shareholders of record as of 18 March 2019. DNO shares will be traded ex-dividend as of 15 March 2019.

(Source: DNO)

Genel Energy gives update on Taq Taq Field

Genel Energy has announced an update on activity at the Taq Taq Field (Genel 44% working interest).

Testing of the TT-32 well has now completed. The well flowed oil from three separate zones, with a maximum individual zone flow rate of c.5,500 bopd with a 36/64″ choke.

The free water level was encountered at 1458 metres, which was 29 metres deeper than the pre-drill estimate and only 57 metres above the original field-wide FWL. The oil column at the TT-32 well location is 169 metres. TT-32 has further demonstrated the remaining potential on the flanks of Taq Taq Field.

The well has now entered production at an initial rate of 3,100 bopd with a 24/64″ choke, ahead of previous expectations. With the inclusion of this production, gross production from the Taq Taq Field is currently c.13,750 bopd.

The horizontal sidetrack well TT-20z spud on 11 January. This well is targeting production from the Shiranish Formation on the western flank of the field, and drilling operations are expected to complete in mid-February.

Three further wells are scheduled to be drilled in 2019, as Genel continues to target the flanks of the field with the aim of delivering a year-on-year production increase.

(Source: Genel Energy)

New Contract for Drilling 40 Wells at Majnoon

By John Lee.

Iraq’s Basra Oil Company (BOC) has agreed a deal with the state-owned Iraqi Drilling Company (IDC) to drill 40 new oil wells in the giant Majnoon oilfield.

In a statement on Thursday, the Ministry of Oil said the aim is to increase production at the field to 450,000 barrels per day (bpd) by 2021.

Reuters estimates current production at around 240,000 bpd.

(Sources: Ministry of Oil, Reuters)

Genel Energy posts strong Trading Update

Genel Energy has issued the following trading and operations update in advance of the Company’s full-year 2018 results, which are scheduled for release on 20 March 2019. The information contained herein has not been audited and may be subject to further review.

Murat Özgül, Chief Executive of Genel, said:

2018 was a very positive year for Genel, which saw us generate material free cash flow and further transform the balance sheet. An expected year-on-year increase in production means we are set to continue this performance in 2019, with low-cost assets forecast to generate over $100 million in free cash flow even if the oil price averages $45/bbl.

“As we generate cash we will continue to invest in the business to maximise the value of our existing portfolio. We are also working hard to bring in new assets that are complementary to our cash generation story. We are focused on building a stronger company with sustainable and material cash flow and multiple growth opportunities from which to create significant shareholder value.

FINANCIAL PERFORMANCE

  • $335 million of cash proceeds were received in 2018 ($263 million in 2017), an increase of 27%, of which $98 million was received in Q4
  • Free cash flow totalled $164 million in 2018 ($99 million in 2017), an increase of 66%, representing a free cash flow yield of 27% on the year-end share price
  • Unrestricted cash balances at 31 December 2018 were $334 million ($162 million at 31 December 2017), with net cash at $37 million ($135 million net debt at 31 December 2017)
  • Capital expenditure for 2018 totalled $95 million, of which $70 million was cost recoverable spend on producing assets

2018 OPERATING PERFORMANCE AND 2019 ACTIVITY OUTLOOK

  • 2018 net production averaged 33,690 bopd, with Q4 averaging 36,920 bopd. Production and sales by asset during 2018 was as follows:

  • Tawke PSC (Genel 25% working interest)
    • Tawke PSC production averaged 113,020 bopd in 2018, with production from Peshkabir contributing 27,660 bopd to this figure
    • Production in Q4 2018 averaged 127,220 bopd, of which Peshkabir contributed 50,130 bopd
    • The Peshkabir-8 well completed in December 2018, and is currently producing just under 10,000 bopd. Results of the Peshkabir-9 well are expected shortly
    • While further production wells are set to be drilled in 2019, Peshkabir activity in 2019 will focus on field management facilities and the utilisation of associated gas to enhance oil recovery at the Tawke field

 

  • Taq Taq PSC (Genel 44% working interest and joint operator)
    • Taq Taq field production averaged 12,350 bopd in 2018
    • Production in Q4 2018 averaged 11,640 bopd
    • Drilling operations on the TT-32 well have now been completed, and test production is underway. The well is currently flowing at a rate of over 3,000 bopd, and still cleaning up, with further zones to be tested ahead of an expected stabilised production rate of c.2,000 bopd
    • The rig has now moved to drill the horizontal sidetrack TT-20z well, which will drill the Shiranish in the western flank of the field with an aim to increasing productivity
    • Three further wells are scheduled to be drilled in 2019, as Genel continues to target the flanks of the field with the aim of delivering a year-on-year production increase

 

  • Bina Bawi and Miran (Genel 100% and operator)
    • Field development plans for both Bina Bawi and Miran oil and gas are under discussion with the KRG, and may entail a phased development approach in order to reduce initial capital expenditure and achieve the earliest date for first gas. An extension to the conditions precedent is expected to be granted shortly
    • Genel is reviewing the value of the Miran PSC carried in the Company accounts, and will update this as part of the year-end results process

 

  • African exploration update
    • Onshore Somaliland, seismic processing has now completed on the SL-10-B/13 block (Genel 75% working interest, operator) and analysis and interpretation is underway. Initial indications confirm the Company view that the block has hydrocarbon potential. Genel continues to develop a prospect inventory and assess next steps ahead of a farm-out process and potentially spudding a well in 2020. On the Odewayne block further seismic processing is being considered in order to complete the Company’s understanding of the prospectivity of the block
    • On the Sidi Moussa block offshore Morocco (Genel 75% working interest, operator), the acquisition of a c.3,500 km2 multi-azimuth broadband 3D seismic survey completed in November. PSTM and PSDM processing will continue through 2019. Genel has no additional work commitments relating to the licence. A decision will be made on whether to drill a well, and the appropriate equity level, once processing has progressed sufficiently

2019 GUIDANCE

  • Genel expects to generate material free cash flow in 2019
    • Genel generates positive free cash flow at and above an oil price of $20/bbl
  • In light of the Company’s balance sheet strength and ongoing material cash generation, management is appraising the most effective model for balanced capital allocation in order to take advantage of growth opportunities, make value accretive additions to the portfolio, and pave the way to returning capital to shareholders at the appropriate time
  • Combined net production from the Tawke and Taq Taq PSCs during 2019 is expected to be close to Q4 2018 levels
  • Capital expenditure net to Genel is forecast to be c.$115 million, with the majority being cost-recoverable spend on current producing assets. Capex includes:
    • Tawke and Taq Taq net to Genel of c.$100 million
    • Bina Bawi and Miran maintenance capex of c.$10 million, with the potential for this figure to be updated should there be positive developments on Bina Bawi commercial discussions
    • African exploration cost of under $5 million, largely comprising processing costs relating to Moroccan seismic
  • Opex: c.$30 million
  • G&A: c.$20 million
  • The Company continues to actively pursue growth and appraise opportunities to make value-accretive additions to the portfolio

(Source: Genel Energy)