Economics-Watching: Kuwait’s Banking Sector Posts Solid Credit Growth in October

[from NBK Group’s Economic Research Department, 21 November, 2024]

Kuwait: Solid credit growth in October driven by household credit. Domestic credit increased by a solid 0.4% in October, driving up YTD growth to 2.9% (3.2% y/y). The recovery in household credit continued, with growth in October at a solid 0.5%, resulting in a YTD increase of 2.4%. While y/y growth in household credit remains a limited 2.3%, annualized growth over the past four months is a stronger 4.7%. Business credit inched up by 0.2% in October, pushing YTD growth to 3.6% (2.9% y/y). Industry and trade drove business credit growth in October while construction and trade are the fastest growing YTD at 17% and 8%, respectively. In contrast, the oil/gas sector continued its downtrend, deepening the YTD decrease to 13%. Excluding the oil/gas sector, growth in business credit would increase to a relatively good 5% YTD. Looking ahead, the last couple of months of the year (especially December) are usually the weakest for business credit, likely due to increased repayments and write-offs, but it will not be surprising if the recovery in household credit is generally sustained, especially given the commencement of the interest rate-cutting cycle. Meanwhile, driven by a plunge in the volatile public-institution deposits, resident deposits decreased in October, resulting in YTD growth of 2.4% (4.2% y/y). Private-sector deposits inched up in October driving up YTD growth to 4.5% compared with 10% for government deposits while public-institution deposits are a big drag (-14%). Within private-sector KD deposits, CASA showed further signs of stabilization as there was no decrease for the third straight month while the YTD drawdown is a limited 1%.

Chart 1: Kuwait credit growth

(% y/y)

Source: Central Bank of Kuwait (CBK)
Chart 2: UK inflation

(%)

Source: Haver

Egypt: IMF concludes mission for fourth review, sees external risks. The IMF concluded its visit to Egypt after spending close to 2 weeks, holding several in-person meetings with the Egyptian authorities, private sector, and other stakeholders. The IMF released a statement mentioning that the current ongoing geopolitical tensions in the region in addition to an increasing number of refugees have affected the external sector (Suez Canal receipts down by 70%) and put severe pressure on the fiscal front. The Fund acknowledged the Central Bank of Egypt’s commitment to unify the exchange rate, maintain the flexible exchange rate regime, and keep inflation on a firm downward trend over the medium term by substantially tightening monetary policy. It also highlighted that continued policy discipline was also a key to containing fiscal risks, especially those related to the energy sector. The Fund, as always, re-iterated the need for promoting the private sector mainly through an enhanced tax system and accelerating divestment plans of the state firms. Finally, it also said that the discussions would continue over the coming days to finalize the agreement on the remaining policies and reform plans. However, the release did not provide any clear hints about the conclusion on the government’s earlier request to push the timeline of some of the subsidy moves.

Oman: IMF completes article IV with a strong outlook for the economy in 2025. Oman’s economy continued to expand with growth reaching 1.9% in the first half of 2024 (versus 1.2% in 2023), despite being weighed down by OPEC+ mandated oil production cuts as non-oil GDP grew a stronger 3.8% y/y in H1 (versus 1.8% in 2023). The fiscal and current account balances remain in a comfortable situation evident by a decline in public sector debt and the recent rating upgrade to investment grade. The Fund expects Oman’s economic growth to see a strong rebound in 2025, supported by higher oil production. It also believes that fiscal and current account balances will remain in surplus but at lower levels. Key risks to the outlook stem from oil price volatility and intensifying geopolitical tensions. The IMF also mentioned that further efforts are needed to raise nonhydrocarbon revenues through more tax policy measures and the phasing out of untargeted subsidies which should help in freeing up resources to finance growth under the government’s diversification agenda.

UK: Inflation rises more than forecast, reinforcing BoE’s caution on rate cuts. UK CPI inflation increased to 2.3% y/y in October from 1.7% the previous month, slightly above the market and the Bank of England’s forecast of 2.2%. On a monthly basis too, inflation rose to 0.6%, a seven-month high, from September’s no change. The steep rise was mainly driven by an almost 10% rise in the household energy price cap effective from October. Core inflation also accelerated to 3.3% y/y (0.4% m/m) from 3.2% (0.1% m/m). While goods prices continued to fall (-0.3% y/y), service prices rose at a faster rate of 5% from 4.9%. Recently, the Bank of England had cautioned about inflation quickening next year (projecting a peak rate of 2.8% in Q3 2025), citing the impact of higher insurance contributions and rising minimum wages as outlined in the latest government budget. Therefore, with inflation rising above forecast, the bank will likely slow the pace of monetary easing after delivering two interest rate cuts of 25 bps earlier, with markets now seeing only two additional cuts by the end of 2025.

Eurozone: ECB warns of fiscal and growth risks in its latest Financial Stability Review [archived PDF]. In its most recent Financial Stability Review (November) [archived PDF], the European Central Bank warned that elevated debt and fiscal deficit levels and anemic long-term growth could expose sovereign debt vulnerabilities in the region, stoking concerns of a repeat of the 2011 sovereign debt crisis. Maturing debt being rolled over at much higher borrowing rates raising debt service costs poses risks to countries with little fiscal space and leaves certain governments exposed to market fluctuations. The bank also emphasized the risks of high equity valuations, low liquidity and a greater concentration of exposure among non-banks. Moreover, it sees current geopolitical uncertainties and the possibility of more trade tensions as heightening risks. The Eurozone’s current government debt-to-GDP ratio stands at 88%, but the underlying data suggest a much more precarious situation with Greece, Italy, and France’s ratios at 164%, 137% and 112%. Recently, concerns about France’s high fiscal deficit (around 5.9% of GDP) and elevated debt levels saw yields on the country’s bonds rise steeply, widening the spread gap with German bonds to the highest level in over a decade.

Stock marketsIndexDaily Change (%)YTD Change (%)
Regional
Abu Dhabi (ADI)9,405-0.23-1.80
Bahrain (ASI)2,043-0.373.62
Dubai (DFMGI)4,7610.6117.26
Egypt (EGX 30)30,588-0.33 23.18
GCC (S&P GCC 40)7090.09-0.52
Kuwait (All Share)7,353-0.087.86
KSA (TASI)11,868-0.07-0.83
Oman (MSM 30)4,6090.002.10
Qatar (QE Index)10,4380.12-3.62
International
CSI 3003,9860.2216.17
DAX19,005-0.2913.45
DJIA43,4080.3215.17
Eurostoxx 504,730-0.454.60
FTSE 1008,085-0.174.55
Nikkei 22538,352-0.1614.61
S&P 5005,9170.0024.05
3m interbank rates%Daily Change (bps)YTD Change (bps)
Bahrain5.86-1.29-66.34
Kuwait3.940.00-37.50
Qatar6.000.00-25.00
UAE4.433.81-89.96
Saudi5.50-4.75-73.14
SOFR4.52-0.09-81.13
Bond yields%Daily Change (bps)YTD Change (bps)
Regional
Abu Dhabi 20274.665.0033.9
Oman 20275.496.0033.0
Qatar 20264.686.0016.1
Kuwait 20274.693.0035.0
Saudi 20284.961.0043.9
International 10-year
US Treasury4.411.7755.3
German Bund2.340.3531.2
UK Gilt4.472.6093.0
Japanese Gov’t Bond1.071.045.4
Exchange ratesRateDaily Change (%)YTD Change (%)
KWD per USD0.310.04-0.05
KWD per EUR0.32-0.46-1.98
USD per EUR1.05-0.49-4.47
JPY per USD155.430.5010.19
USD per GBP1.27-0.25-0.62
EGP per USD49.670.3461.00
Commodities$/unitDaily Change (%)YTD Change (%)
Brent crude72.81-0.68-5.49
KEC73.780.74-7.26
WTI68.87-0.75-3.88
Gold2,648.20.8028.40

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Essay 80: Short-Term Energy Outlook

U.S. Energy Information Administration
November 13, 2019 Release

Highlights

Global liquid fuels
  • Brent crude oil spot prices averaged $60 per barrel (b) in October, down $3/b from September and down $21/b from October 2018. EIA forecasts Brent spot prices will average $60/b in 2020, down from a 2019 average of $64/b. EIA forecasts that West Texas Intermediate (WTI) prices will average $5.50/b less than Brent prices in 2020. EIA expects crude oil prices will be lower on average in 2020 than in 2019 because of forecast rising global oil inventories, particularly in the first half of next year.
  • Based on preliminary data and model estimates, EIA estimates that the United States exported 140,000 b/d more total crude oil and petroleum products in September than it imported; total exports exceeded imports by 550,000 b/d in October. If confirmed in survey-collected monthly data, it would be the first time the United States exported more petroleum than it imported since EIA records began in 1949. EIA expects total crude oil and petroleum net exports to average 750,000 b/d in 2020 compared with average net imports of 520,000 b/d in 2019.
  • Distillate fuel inventories (a category that includes home heating oil) in the U.S. East Coast—Petroleum Administration for Defense District (PADD 1)—totaled 36.6 million barrels at the end of October, which was 30% lower than the five-year (2014–18) average for the end of October. The declining inventories largely reflect low U.S. refinery runs during October and low distillate fuel imports to the East Coast. EIA does not forecast regional distillate prices, but low inventories could put upward pressure on East Coast distillate fuel prices, including home heating oil, in the coming weeks.
  • U.S. regular gasoline retail prices averaged $2.63 per gallon (gal) in October, up 3 cents/gal from September and 11 cents/gal higher than forecast in last month’s STEO. Average U.S. regular gasoline retail prices were higher than expected, in large part, because of ongoing issues from refinery outages in California. EIA forecasts that regular gasoline prices on the West Coast (PADD 5), a region that includes California, will fall as the issues begin to resolve. EIA expects that prices in the region will average $3.44/gal in November and $3.12/gal in December. For the U.S. national average, EIA expects regular gasoline retail prices to average $2.65/gal in November and fall to $2.50/gal in December. EIA forecasts that the annual average price in 2020 will be $2.62/gal.
  • Despite low distillate fuel inventories, EIA expects that average household expenditures for home heating oil will decrease this winter. This forecast largely reflects warmer temperatures than last winter for the entire October–March period, and retail heating oil prices are expected to be unchanged compared with last winter. For households that heat with propane, EIA forecasts that expenditures will fall by 15% from last winter because of milder temperatures and lower propane prices.
Natural gas
  • Natural gas storage injections in the United States outpaced the previous five-year (2014–18) average during the 2019 injection season as a result of rising natural gas production. At the beginning of April, when the injection season started, working inventories were 28% lower than the five-year average for the same period. By October 31, U.S. total working gas inventories reached 3,762 billion cubic feet (Bcf), which was 1% higher than the five-year average and 16% higher than a year ago.
  • EIA expects natural gas storage withdrawals to total 1.9 trillion cubic feet (Tcf) between the end of October and the end of March, which is less than the previous five-year average winter withdrawal. A withdrawal of this amount would leave end-of-March inventories at almost 1.9 Tcf, 9% higher than the five-year average.
  • The Henry Hub natural gas spot price averaged $2.33 per million British thermal units (MMBtu) in October, down 23 cents/MMBtu from September. The decline largely reflected strong inventory injections. However, forecast cold temperatures across much of the country caused prices to rise in early November, and EIA forecasts Henry Hub prices to average $2.73/MMBtu for the final two months of 2019. EIA forecasts Henry Hub spot prices to average $2.48/MMBtu in 2020, down 13 cents/MMBtu from the 2019 average. Lower forecast prices in 2020 reflect a decline in U.S. natural gas demand and slowing U.S. natural gas export growth, allowing inventories to remain higher than the five-year average during the year even as natural gas production growth is forecast to slow. 
  • EIA forecasts that annual U.S. dry natural gas production will average 92.1 billion cubic feet per day (Bcf/d) in 2019, up 10% from 2018. EIA expects that natural gas production will grow much less in 2020 because of the lag between changes in price and changes in future drilling activity, with low prices in the third quarter of 2019 reducing natural gas-directed drilling in the first half of 2020. EIA forecasts natural gas production in 2020 will average 94.9 Bcf/d.
  • EIA expects U.S. liquefied natural gas (LNG) exports to average 4.7 Bcf/d in 2019 and 6.4 Bcf/d in 2020 as three new liquefaction projects come online. In 2019, three new liquefaction facilities—Cameron LNG, Freeport LNG, and Elba Island LNG—commissioned their first trains. Natural gas deliveries to LNG projects set a new record in July, averaging 6.0 Bcf/d, and increased further to 6.6 Bcf/d in October, when new trains at Cameron and Freeport began ramping up. Cameron LNG exported its first cargo in May, Corpus Christi LNG’s newly commissioned Train 2 in July, and Freeport in September. Elba Island plans to ship its first export cargo by the end of this year. In 2020, Cameron, Freeport, and Elba Island expect to place their remaining trains in service, bringing the total U.S. LNG export capacity to 8.9 Bcf/d by the end of the year.
Electricity, coal, renewables, and emissions
  • EIA expects the share of U.S. total utility-scale electricity generation from natural gas-fired power plants will rise from 34% in 2018 to 37% in 2019 and to 38% in 2020. EIA forecasts the share of U.S. electric generation from coal to average 25% in 2019 and 22% in 2020, down from 28% in 2018. EIA’s forecast nuclear share of U.S. generation remains at about 20% in 2019 and in 2020. Hydropower averages a 7% share of total U.S. generation in the forecast for 2019 and 2020, down from almost 8% in 2018. Wind, solar, and other non-hydropower renewables provided 9% of U.S. total utility-scale generation in 2018. EIA expects they will provide 10% in 2019 and 12% in 2020.
  • EIA expects total U.S. coal production in 2019 to total 698 million short tons (MMst), an 8% decrease from the 2018 level of 756 MMst. The decline reflects lower demand for coal in the U.S. electric power sector and reduced competitiveness of U.S. exports in the global market. EIA expects U.S. steam coal exports to face increasing competition from Eastern European sources, and that Russia will fill a growing share of steam coal trade, causing U.S. coal exports to fall in 2020. EIA forecasts that coal production in 2020 will total 607 MMst.
  • EIA expects U.S. electric power sector generation from renewables other than hydropower—principally wind and solar—to grow from 408 billion kilowatt-hours (kWh) in 2019 to 466 billion kWh in 2020. In EIA’s forecast, Texas accounts for 19% of the U.S. non-hydropower renewables generation in 2019 and 22% in 2020. California’s forecast share of non-hydropower renewables generation falls from 15% in 2019 to 14% in 2020. EIA expects that the Midwest and Central power regions will see shares in the 16% to 18% range for 2019 and 2020.
  • EIA forecasts that, after rising by 2.7% in 2018, U.S. energy-related carbon dioxide (CO2) emissions will decline by 1.7% in 2019 and by 2.0% in 2020, partially as a result of lower forecast energy consumption. In 2019, EIA forecasts less demand for space cooling because of cooler summer months; an expected 5% decline in cooling degree days from 2018, when it was significantly higher than the previous 10-year (2008–17) average. In addition, EIA also expects U.S. CO2 emissions in 2019 to decline because the forecast share of electricity generated from natural gas and renewables will increase, and the share generated from coal, which is a more carbon-intensive energy source, will decrease.