Category: Ukraine

  • MIL-OSI: Credit Agricole Sa: Third quarter and first nine months 2024 results – VERY STRONG QUARTER, 2024 INCOME TARGET CONFIRMED

    Source: GlobeNewswire (MIL-OSI)

    VERY STRONG QUARTER, 2024 INCOME TARGET CONFIRMED
    CASA AND CAG STATED AND UNDERLYING DATA Q3-2024
               
      CRÉDIT AGRICOLE S.A.   CRÉDIT AGRICOLE GROUP
        Stated   Underlying     Stated   Underlying
    Revenues   €6,487m
    +2.3% Q3/Q3
      €6,484m
    +7.0% Q3/Q3
        €9,213m
    -0.4% Q3/Q3
      €9,210m
    +4.1% Q3/Q3
    Expenses   -€3,689m
    +9.2% Q3/Q3
      -€3,654m
    +8.2% Q3/Q3
        -€5,590m
    +6.2% Q3/Q3
      -€5,556m
    +5.5% Q3/Q3
    Gross Operating Income   €2,799m
    -5.7% Q3/Q3
      €2,830m
    +5.5% Q3/Q3
        €3,623m
    -9.1% Q3/Q3
      €3,654m
    +2.0% Q3/Q3
    Cost of risk   -€433m
    +0.9% Q3/Q3
      -€433m
    +0.9% Q3/Q3
        -€801m
    +15.6% Q3/Q3
      -€801m
    +15.6% Q3/Q3
    Net income group share   €1,666m
    -4.7% Q3/Q3
      €1,686m
    +10.9% Q3/Q3
                €2,080m

    -12.8% Q3/Q3

      €2,100m
    +1.5% Q3/Q3
    C/I ratio   56.9%
    +3.6 pp Q3/Q3
      56.4%
    +0.6 pp Q3/Q3
        60.7%
    +3.7 pp Q3/Q3
      60.3%
    +0.8 pp Q3/Q3
    RESULTS UP FOR THE FIRST NINE MONTHS OF THE YEAR; TARGET CONFIRMED OF >€6BN IN NET INCOME GROUP SHARE FOR 2024

    STRONG QUARTERLY RESULT

    • +8.2% growth in net income Group share excluding base effect related to reversals of Home Purchase Savings Plan provisions in Q3-23
    • High level of revenues, sharply up in underlying vision
    • Low cost/income ratio; support for business line development with a +4.1% increase in recurring expenses

    STRONG ACTIVITY IN ALL BUSINESS LINES

    • Solid performance in retail banking and consumer finance, supported by a good level of customer capture, higher on-balance sheet deposits in France and stable on-balance sheet deposits in Italy, gradual recovery in home loan activity and increased corporate loan production in France, continued momentum in international loan activity, and consumer finance activity stable at a high level
      • Excellent business momentum in CIB, asset management and insurance, reflected in high gross inflows in life insurance, continued brisk business in property and casualty and personal insurance, solid level of inflows and a record level of assets under management, CIB business still robust and record nine-month revenues

    CONTINUED STRATEGIC PROJECTS

    • Partnership with GAC in China on leasing and in Europe on automotive financing
    • Signing of an agreement to acquire Merca Leasing
    • Acquisition of Nexity Property Management

    VERY SOLID CAPITAL AND LIQUIDITY POSITIONS

    • Crédit Agricole S.A. phased-in CET1 11.7%
    • CA Group phased-in CET1 17.4%
     

    Dominique Lefebvre,
    Chairman of SAS Rue La Boétie and Chairman of the Crédit Agricole S.A. Board of Directors

    The Group reports solid results this quarter. These results reinforce its desire to be useful to all its customers and to play a leading role in actively supporting the economy.”  

     
     

    Philippe Brassac,
    Chief Executive Officer of Crédit Agricole S.A.

    Quarter after quarter, the Group publishes high-level results confirming the outlook for a 2024 result that is one year ahead of Crédit Agricole S.A.’s Ambitions for 2025.”

     

    This press release comments on the results of Crédit Agricole S.A. and those of Crédit Agricole Group, which comprises the Crédit Agricole S.A. entities and the Crédit Agricole Regional Banks, which own 62.4% of Crédit Agricole S.A. Please see the appendices to this press release for details of specific items, which are restated in the various indicators to calculate underlying income.

    Crédit Agricole Group

    Group activity

    The Group’s commercial activity during the quarter continued at a steady pace across all business lines, with a good level of customer capture. During the third quarter of 2024, the Group recorded +482,000 new customers in retail banking, and the customer base grew by +104,000 customers. More specifically, over the quarter, the Group recorded +383,000 new customers for Retail Banking in France and +99,000 new International Retail Banking customers (Italy and Poland), and the customer base also grew (+64,000 and +40,000 customers, respectively).

    At 30 September 2024, retail banking on-balance sheet deposits totalled €830 billion, up +2.8% year-on-year in France and Italy (+3.1% for Regional Banks and LCL and -0.4% in Italy). Outstanding loans totalled €876 billion, up +0.4% year-on-year in France and Italy (+0.2% for Regional Banks and LCL and +3.0% in Italy). Home loan production picked up gradually in France during this quarter, recording an increase of +20% for the Regional Banks and +73% for LCL compared to the second quarter of 2024, and -11% and +17% respectively compared to the third quarter of 2023. In Italy, home loan production was down -12% for CA Italy due to a base effect related to successful marketing campaigns in the third quarter of 2023. However, they were still up on second quarter 2024. The property and casualty insurance equipment rate1 rose to 43.8% for the Regional Banks (+0.7 percentage points compared to the third quarter of 2023), 27.9% for LCL (+0.3 percentage point) and 20.0% for CA Italy (+1.7 percentage point).

    In asset management, inflows remained healthy (+€14.4 billion excluding an insurance mandate withdrawal totalling -€11.6 billion), particularly with regard to medium/long-term assets excluding JVs (+€9 billion). Commercial momentum within JVs was also solid. In savings/retirement, Crédit Agricole Assurances posted a high level of gross inflows (€7.2 billion, up +56% year-on-year), the unit-linked rate remained high in production (32.8%), and net inflows were positive (+€1.6 billion) and growing. In property and casualty insurance, the portfolio grew by +5.1% year-on-year to 16.6 million policies. Assets under management were once again at their highest level ever, rising compared to the end of September 2023 in asset management (€2,192 billion, or +11.1%), life insurance (€343.2 billion, or +5.8%) and wealth management, which benefited from the integration of Degroof Petercam (IWM and Private Banking of LCL €274 billion, or +46.9%).

    SFS business line registered an activity stable at a high level, with an increase in consumer finance outstandings at CAPFM (+5.2% compared to the end of September 2023), driven by automotive activities, which account for 53%2 of total outstandings, and growth in production and leasing outstandings at CAL&F (€20.1 billion, or +8.8% compared to the end of September 2023).

    Momentum is strong in Large Customers, with record revenues in corporate and investment banking (best nine-month cumulative total), with capital markets and investment banking being driven by capital market activities, and financing activities benefiting from growth in commercial banking. CACEIS also posted a high level of assets under custody (€5,061 billion, +12.1% compared to the end of September 2023) and assets under administration (€3,386 billion, +4.2% compared to the end of September 2023). It benefited during the quarter from strong commercial momentum and positive market effects.

    Each of the Group’s business lines posted strong activity (see Infra).

    Continued support of transition

    Crédit Agricole Assurances has set out its new climate commitments, announcing its target to reduce carbon intensity of its portfolio3 by -50% by 2029 (compared to 2019).

    Crédit Agricole Group has also decided to participate in CDC’s energy and ecological transition financing support scheme. The Group will thus be able to raise up to €5.3 billion in liquidity by November 2025, exclusively for financing new projects contributing to the energy and ecological transition.

    The Group is continuing the mass roll-out of financing and investment to promote the transition. As such, the Crédit Agricole Group doubled its exposure to low-carbon energy financing4 between the end of 2020 and September 2024, with €21.9 billion at 30 September 2024. In addition, Crédit Agricole Assurances’s financing of renewable energy production capacity increased by +17% compared to the end of 2022, representing 13.8 gigawatts at 30 June 2024.

    Lastly, Crédit Agricole CIB’s green loan portfolio5 grew by +67% between the end of 2022 and September 2024, and represented €20.7 billion at 30 September 2024.

    Group results

    In the third quarter of 2024, the Crédit Agricole Group’s stated net income Group share came to €2,080 million, down -12.8% compared to the third quarter of 2023. This was due to significant specific items in the third quarter of 2023.

    Specific items in the third quarter of 2024 had a negative net impact of -€20 million on the net income Group share of the Crédit Agricole Group. These items comprise the following recurring accounting items: recurring accounting volatility items, namely the DVA (Debt Valuation Adjustment), the issuer spread portion of the FVA, and secured lending for +€3 million in net income Group share from capital markets and investment banking, and the hedging of the loan book in Large Customers for -€1 million in net income Group share. In addition to these recurring items, there were other items specific to this quarter: ISB integration costs of -€14 million in net income Group share of Large Customers, the Degroof Petercam integration costs of -€6 million in net income Group share of Asset Gathering, and the acquisition costs of Degroof Petercam totalling -€2 million in net income Group share of private banking.

    Specific items in the third quarter of 2023 had a cumulative positive impact of +€317 million in net income Group share and comprised DVA and hedging items for +€1 million under Large Customers, reversals of the Home Purchase Savings Plan provisions for +€297 million (+€38 million for LCL, +€171 million for the Corporate Centre and +€88 million for the Regional Banks), and the impact of the SFS division’s Mobility6 business for -€26 million under the equity method and +€45 million under gains and losses on other assets.

    Excluding these specific items, Crédit Agricole Group’s underlying net income Group share7 amounted to €2,100 million, up +1.5% compared to third quarter 2023.

    Crédit Agricole Group – Stated and underlying results, Q3-24 and Q3-23

    €m Q3-24
    stated
    Specific items Q3-24
    underlying
    Q3-23
    stated
    Specific items Q3-23
    underlying
    ∆ Q3/Q3
    stated
    ∆ Q3/Q3
    underlying
                     
    Revenues 9,213 3 9,210 9,249 402 8,847 (0.4%) +4.1%
    Operating expenses excl.SRF (5,590) (34) (5,556) (5,265) 0 (5,265) +6.2% +5.5%
    SRF n.m. n.m.
    Gross operating income 3,623 (31) 3,654 3,984 402 3,582 (9.1%) +2.0%
    Cost of risk (801) 0 (801) (693) 0 (693) +15.6% +15.6%
    Equity-accounted entities 61 61 37 (26) 63 +65.7% (3.5%)
    Net income on other assets (5) (3) (2) 69 61 9 n.m. n.m.
    Change in value of goodwill n.m. n.m.
    Income before tax 2,877 (34) 2,912 3,397 436 2,961 (15.3%) (1.6%)
    Tax (587) 8 (595) (810) (120) (691) (27.6%) (13.8%)
    Net income from discont’d or held-for-sale ope. 2 2 (100.0%) (100.0%)
    Net income 2,291 (26) 2,317 2,588 317 2,272 (11.5%) +2.0%
    Non controlling interests (211) 6 (217) (204) (204) +3.4% +6.5%
    Net income Group Share 2,080 (20) 2,100 2,384 317 2,068 (12.8%) +1.5%
    Cost/Income ratio excl.SRF (%) 60.7%   60.3% 56.9%   59.5% +3.7 pp +0.8 pp

    In the third quarter of 2024, underlying revenues amounted to €9,210 million, up +4.1% compared to the third quarter of 2023, driven by favourable results from most of the business lines. Underlying revenues were up in French Retail Banking (+1.8%), while the Asset Gathering division benefited from good business momentum and the integration of Degroof Petercam, and the Large Customers division enjoyed a high level of revenues across all of its business lines, in addition to the integration of ISB. Meanwhile, revenues were down slightly for International Retail Banking and Specialised Financial Services, which were penalised by the drop in interest rates. Underlying operating expenses increased by +5.5% in the third quarter of 2024 to €5,556 million. This was due to scope effects, base effects on taxes and support for business line development. Overall, the Group saw its underlying cost/income ratio reach 60.3% in the third quarter of 2024, a moderate rise of +0.8 percentage point. As a result, the underlying gross operating income stood at €3,654 million, up +2.0% compared to the third quarter of 2023.

    The underlying cost of credit risk stood at -€801 million, a year-on-year increase of +15.6%. This figure comprises an addition of -€93 million for prudential provisions on performing loans (stages 1 and 2), an addition of -€709 million for the cost of proven risk (stage 3), the consequence of an increase in defaults in the corporate market, and additional provisioning for a number of corporate-specific files. There was also a reversal of +€1 million on other risks. The provisioning levels were determined by taking into account several weighted economic scenarios and by applying some flat-rate adjustments on sensitive portfolios. The weighted economic scenarios for the third quarter were unchanged from the second quarter, with a favourable scenario (French GDP at +1.2% in 2024, +1.5% in 2025) and an unfavourable scenario (French GDP at -0.2% in 2024 and +0.5% in 2025). The cost of risk/outstandings8reached 26 basis points over a four rolling quarter period and 27 basis points on an annualised quarterly basis9.

    Underlying pre-tax income stood at €2,912 million, a year-on-year decrease of -1.6%. This includes the contribution from equity-accounted entities of €61 million (down -3.5%) and net income on other assets, which came to -€2 million this quarter. The underlying tax charge fell by -13.8% over the period, the tax rate this quarter falling by -3.0 percentage points to 20.9%. Underlying net income before non-controlling interests was up +2.0% to €2,317 million. Non-controlling interests rose +6.5%. Lastly, underlying net income Group share was €2,100 million, +1.5% higher than in the third quarter of 2023.

    Crédit Agricole Group – Stated and underlying results 9M-24 and 9M-23

    €m 9M-24
    stated
    Specific items 9M-24
    underlying
    9M-23
    stated
    Specific items 9M-23
    underlying
    ∆ 9M/9M
    stated
    ∆ 9M/9M
    underlying
                     
    Revenues 28,244 117 28,127 27,722 758 26,965 +1.9% +4.3%
    Operating expenses excl.SRF (16,866) (84) (16,782) (15,782) (18) (15,764) +6.9% +6.5%
    SRF (620) (620) (100.0%) (100.0%)
    Gross operating income 11,378 33 11,345 11,321 739 10,581 +0.5% +7.2%
    Cost of risk (2,324) (20) (2,304) (2,179) (84) (2,095) +6.6% +10.0%
    Equity-accounted entities 203 (0) 203 190 (39) 229 +6.7% (11.2%)
    Net income on other assets (19) (23) 4 107 89 18 n.m. (78.5%)
    Change in value of goodwill n.m. n.m.
    Income before tax 9,238 (10) 9,248 9,438 705 8,733 (2.1%) +5.9%
    Tax (2,104) (4) (2,100) (2,293) (180) (2,113) (8.2%) (0.6%)
    Net income from discont’d or held-for-sale ope. 7 7 (100.0%) (100.0%)
    Net income 7,134 (14) 7,148 7,153 525 6,628 (0.3%) +7.9%
    Non controlling interests (643) 17 (659) (619) (0) (619) +3.8% +6.5%
    Net income Group Share 6,491 3 6,489 6,534 525 6,009 (0.6%) +8.0%
    Cost/Income ratio excl.SRF (%) 59.7%   59.7% 56.9%   58.5% +2.8 pp +1.2 pp

    In the first nine months of 2024, stated net income Group share amounted to €6,491 million, compared with €6,534 million in the first nine months of 2023, a difference of just -0.6%.

    Specific items for the first nine months of 2024 include the specific items of the Regional Banks for the first nine months of 2024 (+€47 million in reversals of Home Purchase Savings Plan provisions) and Crédit Agricole S.A. specific items, which are detailed in the Crédit Agricole S.A. section.

    Excluding specific items, underlying net income Group share reached €6,489 million, up +8.0% compared to the first nine months of 2023.

    Underlying revenues totalled €28,127 million, up +4.3% compared to the first nine months of 2023. This increase is attributable to growth in all business lines, reaching a total, excluding the Corporate Centre division, of +4.6% compared to the first nine months of 2023.

    Underlying operating expenses amounted to -€16,782 million, up +6.5% excluding SRF compared to the first nine months of 2023, mainly due to higher compensation in an inflationary environment, support for business development, IT expenditure and scope effects as detailed for each division. The underlying cost/income ratio for the first nine months of 2024 was 59.7%, up +1.2 percentage points compared to the first nine months of 2023 excluding SRF. The SRF stood at -€620 million in 2023.

    Underlying gross operating income totalled €11,345 million, up +7.2% compared to the first nine months of 2023.

    The underlying cost of risk for the first nine months of 2024 rose to -€2,304 million (of which -€178 million in cost of risk on performing loans (stages 1 and 2), -€2,148 million in cost of proven risk, and +€22 million in other risks corresponding mainly to reversals of legal provisions), i.e. an increase of +10.0% compared to the first nine months of 2023.

    As at 30 September 2024, risk indicators confirm the high quality of Crédit Agricole Group’s assets and risk coverage level. The diversified loan book is mainly geared towards home loans (45% of gross outstandings) and corporates (33% of gross outstandings). Loan loss reserves amounted to €21.3 billion at the end of September 2024 (€11.7 billion for Regional Banks), 41% of which represented provisioning of performing loans (47% for Regional Banks). The prudent management of these loan loss reserves meant that the Crédit Agricole Group’s overall coverage ratio for doubtful loans at the end of September 2024 was 82.8%.

    Underlying net income on other assets stood at €4 million in the first nine months of 2024, versus €18 million in the first nine months of 2023. Underlying pre-tax income before discontinued operations and non-controlling interests rose by +5.9% to €9,248 million. The tax charge was -€2,100 million, a change of just -0.6%, with an underlying effective tax rate of 23.2%, down -1.6 percentage points compared to the first nine months of 2023. Underlying net income before non-controlling interests was therefore up by +7.9%. Non-controlling interests amounted to -€659 million in the first nine months of 2023, up +6.5%.

    Underlying net income Group share for first nine months of 2024 thus stood at €6,489 million, up +8.0% compared to the first nine months of 2023.

    Regional banks

    Gross customer capture stands at +275,000 new customers and the customer base grew by +27,000 new customers over the same period. The percentage of customers using demand deposits as their main account and those who use digital tools continued to increase.

    Loan production was down -7% compared to the third quarter of 2023, reflecting the -11% drop in home loans and the decline in specialised markets. Home loan production has been gradually recovering since the beginning of the year (+20% compared to the second quarter 2024). The average lending production rate for home loans stood at 3.47%10 over July and August 2024, -16 basis points lower than in the second quarter of 2024. By contrast, the global loan stock rate showed a gradual improvement (+27 basis points compared to the third quarter of 2023). Outstanding loans totalled €646 billion at the end of September 2024, stable year-on-year across all markets but up slightly by +0.5% over the quarter.

    Customer assets were up +3.6% year-on-year to reach €903 billion at the end of September 2024. This growth was driven both by on-balance sheet deposits, which reached €601 billion (+2.5% compared to end September year-on-year), and off-balance sheet deposits, which reached €302 billion (+5.9% year-on-year) benefiting from favourable market effects and strong inflows in unit-linked bonds (€8 billion cumulative year-on-year). The mix of on-balance sheet deposits for the quarter remained almost unchanged, with demand deposits and term deposits fluctuating by -0.6% and +1% respectively from end-June 2024.

    The equipment rate for property and casualty insurance11 was 43.8% at the end of September 2024 and continues to rise (up +0.7 percentage point compared to the end of September 2023). In terms of payment instruments, the number of cards rose by +1.7% year-on-year, as did the percentage of premium cards in the stock, which increased by 1.9 percentage points year-on-year to account for 16.0% of total cards.

    In the third quarter of 2024, the Regional Banks’ consolidated revenues including the SAS Rue La Boétie dividend12 stood at €3,220 million, down -2.1% compared to the third quarter of 2023, notably impacted by a base effect of +€118 million13 related to the reversal of the Home Purchase Savings Plan provision in the third quarter of 2023. Excluding this item, revenues were up +1.5% year-on-year, the decline in the net interest margin (-11.6% excluding the Home Purchase Savings Plan13 base effect) being offset by the rise in portfolio revenues (+41.8%) and fee and commission income (+4.9%), itself driven by buoyant business in life insurance and account management. Operating expenses were up +3.5%, due to an increase in staff costs, property expenses and IT costs. Gross operating income was down -15.3% year-on-year (-3.8% excluding the Home Purchase Savings Plan13 base effect). The cost of risk was up by +43.7% compared to the third quarter of 2023 to stand at -€369 million. mainly due to the increase in proven risk in the corporate sector. Cost of risk/outstandings remained under control, at 22 basis points.

    The Regional Banks’ consolidated net income, including the SAS Rue La Boétie dividend,12 amounted to €351 million, down -38.0% compared to the third quarter of 2023 (-26.5% excluding the base effect13).

    The Regional Banks’ contribution to net income Group share was €371 million in the third quarter of 2024, down -36.9% compared to the third quarter of 2023.

    In the first nine months of 2024, revenues including the SAS Rue La Boétie dividend were up +2.2% compared to the same period in 2023. Operating expenses rose by +1.7%, resulting in a rise in gross operating income of +3% for the first nine months of 2024. Finally, with a cost of risk up +29%, the Regional Banks’ net income Group share, including the SAS Rue La Boétie dividend, amounted to €3,051 million, up +0.5% compared to the first nine months of 2023 (+1.9% excluding the Home Purchase Savings Plan base effect).

    The Regional Banks’ contribution to the results of Crédit Agricole Group in the first nine months of 2024 amounted to €1,021 million in stated net income Group share (-28.1% compared to the same period in 2023), with revenues of €9,834 million (-2%), expenses of -€7,453 (+3.3%) and a cost of risk of -€1,056 million (+27%).

    Crédit Agricole S.A.

    Results

    Crédit Agricole S.A.’s Board of Directors, chaired by Dominique Lefebvre, met on 5 November 2024 to examine the financial statements for third quarter 2024.

    Crédit Agricole S.A. – Stated and underlying results, Q3-24 and Q3-23

    €m Q3-24
    stated
    Specific items Q3-24
    underlying
    Q3-23
    stated
    Specific items Q3-23
    underlying
    ∆ Q3/Q3
    stated
    ∆ Q3/Q3
    underlying
                     
    Revenues 6,487 3 6,484 6,343 284 6,060 +2.3% +7.0%
    Operating expenses excl.SRF (3,689) (34) (3,654) (3,376) 0 (3,376) +9.2% +8.2%
    SRF n.m. n.m.
    Gross operating income 2,799 (31) 2,830 2,967 284 2,684 (5.7%) +5.5%
    Cost of risk (433) 0 (433) (429) 0 (429) +0.9% +0.9%
    Equity-accounted entities 42 42 23 (26) 50 +81.3% (15.3%)
    Net income on other assets (4) (3) (1) 69 61 8 n.m. n.m.
    Change in value of goodwill n.m. n.m.
    Income before tax 2,404 (34) 2,438 2,630 318 2,312 (8.6%) +5.4%
    Tax (476) 8 (484) (633) (89) (544) (24.8%) (11.0%)
    Net income from discont’d or held-for-sale ope. 2 2 n.m. n.m.
    Net income 1,928 (26) 1,954 1,999 229 1,770 (3.5%) +10.4%
    Non controlling interests (262) 6 (268) (251) (2) (250) +4.2% +7.5%
    Net income Group Share 1,666 (20) 1,686 1,748 227 1,520 (4.7%) +10.9%
    Earnings per share (€) 0.50 (0.01) 0.51 0.53 0.07 0.46 (5.5%) +11.4%
    Cost/Income ratio excl. SRF (%) 56.9%   56.4% 53.2%   55.7% +3.6 pp +0.6 pp

    In the third quarter of 2024, Crédit Agricole S.A.’s stated net income Group share came to €1,666 million, down -4.7% compared to the third quarter of 2023, having benefited from non-recurring items related to reversals of the Home Purchase Savings Plan provisions (see below). This was an excellent result for the third quarter of 2024, based on high revenues and a cost/income ratio kept at a low level.

    Specific items for this quarter had a cumulative impact of -€20 million on net income Group share, and included the following recurring accounting items: recurring accounting volatility items in revenues, such as the DVA (Debt Valuation Adjustment), the issuer spread portion of the FVA and secured lending for +€3 million in net income Group share in the Large Customers segment, and the hedging of the loan book in the Large Customers segment for -€1 million in net income Group share. In addition to these recurring items, there were a number of items specific to this quarter: Degroof Petercam integration costs of -€6 million in the net income Group share in Asset Gathering; ISB integration costs for -€14 million in the net income Group share in Large Customers, and the acquisition costs of Degroof Petercam for -€2 million in the net income Group share in Asset Gathering.

    Specific items for the third quarter of 2023 had a cumulative impact of +€227 million on net income Group share, and comprised recurring accounting items amounting to +€208 million (primarily reversals of Home Purchase Savings Plan provisions for +€37 million at LCL and +€171 million at the Corporate Centre). Non-recurring items were related to the ongoing reorganisation of the SFS division’s Mobility business amounting to +€19 million.

    Excluding a positive base effect related to the reversals of Home Purchase Savings Plan provisions, net income Group share was up +8.2% for the period.

    Excluding specific items, underlying net income Group share14 stood at €1,686 million in the third quarter of 2024, up +10.9% compared to the third quarter of 2023.

    In the third quarter of 2024, underlying revenues were at a high level, standing at €6,484 million. They were up sharply by +7.0% compared to the third quarter of 2023. This growth was driven by the Asset Gathering business line, which recorded growth of +12.9% as a result of strong business momentum and the integration of Degroof Petercam15; the Large Customers business line (+8.7%), which saw good results from all business lines with continued revenue growth in the third quarter in Corporate and Investment Banking, in addition to an improvement in the net interest margin and fee and commission income within CACEIS; Specialised Financial Services (-1.5%), which benefited from favourable scope and volume effects as well as a more stable margin in the Personal Finance and Mobility business line; French Retail Banking (+3.7%), which was boosted by an improved net interest margin and higher fee and commission income; and lastly, International Retail Banking (-1.8%), which was essentially impacted by the decline in the net interest margin in Italy. The Corporate Centre division recorded an increase in revenues of +€43 million.

    Underlying operating expenses totalled -€3,654 million in the third quarter of 2024, an increase of +8.2% compared to the third quarter of 2023, reflecting the support given to business line development. The -€278 million year-on-year increase in expenses was mainly due to a -€112 million scope effect,16 integration costs of -€29 million17, and a positive tax-related base effect of -€30 million. Recurring expenses were up by -€141 million, or +4.1% (-€38 million in staff costs, -€76 million in IT investments and -€27 million in other expenses).

    The underlying cost/income ratio in the third quarter of 2024 thus stood at 56.4%, an increase of +0.6 percentage points compared to the third quarter of 2023.

    Underlying gross operating income in the third quarter of 2024 stood at €2,830 million, an increase of +5.5% compared to the third quarter of 2023. It was up +4.2% when restated solely for reversals of the Home Purchase Savings Plan provisions.

    As at 30 September 2024, risk indicators confirm the high quality of Crédit Agricole S.A.’s assets and risk coverage level. The diversified loan book is mainly geared towards home loans (26% of gross outstandings) and corporates (43% of Crédit Agricole S.A. gross outstandings). The Non Performing Loans ratio showed little change from the previous quarter and remained low at 2.5%. The coverage ratio18 was high at 71.4%, up +0.1 percentage points over the quarter. Loan loss reserves amounted to €9.6 billion for Crédit Agricole S.A., a -€0.1 billion decline from end-June 2024. Of those loan loss reserves, 34% were for performing loans (percentage in line with previous quarters).

    The underlying cost of risk showed a net addition of -€433 million, up +0.9% from the third quarter of 2023, which included a -€38 million addition for performing loans (stages 1 and 2) (versus a reversal of +€59 million in the third quarter of 2023) and -€388 million in provisioning for proven risks (stage 3) (versus -€487 million in the third quarter of 2023). There was also a small addition of -€7 million for other items (legal provisions). By business line, 52% of the net addition for the quarter came from Specialised Financial Services (unchanged from end-September 2023), 19% from LCL (16% at end-September 2023), 14% from International Retail Banking (28% at end-September 2023), 4% from Large Customers (3% at end-September 2023) and 8% from the Corporate Centre (zero at end-September 2023). The increase in the cost of risk for the Corporate Centre was mainly due to the increase in the risk on financing secured by Foncaris. The provisioning levels were determined by taking into account several weighted economic scenarios and by applying some flat-rate adjustments on sensitive portfolios. The weighted economic scenarios for the third quarter were unchanged from the second quarter, with a favourable scenario (French GDP at +1.2% in 2024, +1.5% in 2025) and an unfavourable scenario (French GDP at -0.2% in 2024 and +0.5% in 2025). In the third quarter of 2024, the cost of risk/outstandings was 32 basis points over a rolling four-quarter period19 and 32 basis points on an annualised quarterly basis20 (an improvement of 1 basis point compared to the third quarter of 2023 for both bases).

    The underlying contribution from equity-accounted entities amounted to €42 million in the third quarter of 2024, down -15.3% compared to the third quarter of 2023, driven in particular by the strong growth of equity-accounted entities in asset management and a decline in the Personal Finance and Mobility business line.

    Underlying income21before tax, discontinued operations and non-controlling interests was up +5.4% to €2,438 million. The underlying effective tax rate stood at 20.2%, i.e. down -3.8 percentage points compared to the third quarter of 2023. The underlying tax charge was -€484 million, down -11% mainly due to the impact of reduced-tax disposals of equity interests and the revaluation of securities at fair value in the Insurance business line, partially offset by the increase in the tax rate in Ukraine. Underlying net income before non-controlling interests was up +10.4% to €1,954 million. Non-controlling interests amounted to -€268 million in the third quarter of 2024, an increase of +7.5%.

    Underlying earnings per share in third quarter of 2024 reached €0.51, increasing by +11.4% compared to the third quarter of 2023.

    Crédit Agricole S.A. – Stated and underlying results, 9M-24 and 9M-23

    €m 9M-24
    stated
    Specific items 9M-24
    underlying
    9M-23
    stated
    Specific items 9M-23
    underlying
    ∆ 9M/9M
    stated
    ∆ 9M/9M
    underlying
                     
    Revenues 20,089 53 20,036 19,140 598 18,542 +5.0% +8.1%
    Operating expenses excl.SRF (10,978) (84) (10,894) (9,922) (18) (9,904) +10.6% +10.0%
    SRF (509) (509) (100.0%) (100.0%)
    Gross operating income 9,111 (30) 9,141 8,709 580 8,129 +4.6% +12.5%
    Cost of risk (1,256) (20) (1,236) (1,338) (84) (1,253) (6.1%) (1.3%)
    Equity-accounted entities 132 (0) 132 136 (39) 175 (3.4%) (24.7%)
    Net income on other assets 5 (23) 28 102 89 13 (95.3%) x 2.1
    Change in value of goodwill n.m. n.m.
    Income before tax 7,991 (73) 8,064 7,609 545 7,064 +5.0% +14.2%
    Tax (1,790) 12 (1,803) (1,832) (149) (1,682) (2.3%) +7.1%
    Net income from discont’d or held-for-sale ope. 7 7 n.m. n.m.
    Net income 6,201 (61) 6,262 5,785 396 5,389 +7.2% +16.2%
    Non controlling interests (803) 16 (820) (771) (2) (769) +4.2% +6.6%
    Net income Group Share 5,397 (45) 5,442 5,014 394 4,620 +7.6% +17.8%
    Earnings per share (€) 1.59 (0.01) 1.60 1.53 0.13 1.40 +3.8% +14.5%
    Cost/Income ratio excl.SRF (%) 54.6%   54.4% 51.8%   53.4% +2.8 pp +1.0 pp

    In the first nine months of 2024, stated net income Group share amounted to €5,397 million, compared with €5,014 million in the first nine months of 2023, an increase of +7.6%.

    Specific items in the first nine months of 2024 had a negative impact of -€45 million on stated net income Group share, and comprise +€39 million in recurring accounting items and -€84 million in non-recurring items. The recurring items mainly correspond to the reversals of and additions to the Home Purchase Savings Plans provisions for +€1 million net, as well as the accounting volatility items of the Large Customers division (the DVA for +€33 million and loan book hedging for +€5 million). Non-recurring items relate to the costs of integrating and acquiring Degroof Petercam (-€27 million) within the Asset Gathering division, the costs of integrating (-€37 million) and acquiring (-€17 million) ISB within the Large Customers division and an additional provision for risk in Ukraine (-€20 million) within the International Retail Banking division.

    Excluding specific items, underlying Net income Group share reached €5,442 million, up +17.8% compared to the first nine months of 2023.

    Underlying revenues were up +8.1% compared to the first nine months of 2023, driven by all business lines. Underlying operating expenses were +10% higher than in 2023, essentially reflecting the development of the Group’s business lines and the integration of scope effects, partially offset by the end of the SRF22 building-up period. The underlying cost/income ratio excluding SRF for the period was 54.4%, an increase of 1 percentage point compared to the same period in 2023. Underlying gross operating income totalled €9,141 million, up +12.5% compared to the first nine months of 2023. The underlying cost of risk decreased by -1.3% over the period to -€1,236 million, versus -€1,253 million in 2023. Lastly, underlying contributions from equity-accounted entities amounted to €132 million, down -24.7% over the period.

    Underlying earnings per share were €1.60 per share in the first nine months of 2024, up +14.5% compared to the first nine months of 2023.

    Underlying RoTE 23, which is calculated on the basis of an annualised underlying Net Income Group Share 24 and IFRIC charges linearised over the year, net of annualised Additional Tier 1 coupons (return on equity Group share excluding intangibles) and net of foreign exchange impact on reimbursed AT1, and restated for certain volatile items recognised in equity (including unrealised gains and/or losses), reached 14.5% over the first nine months of 2024, up by +1 percentage point compared to the first nine months of 2023.

    Analysis of the activity and the results of Crédit Agricole S.A.’s divisions and business lines

    Activity of the Asset Gathering division

    In the third quarter of 2024, assets under management in the Asset Gathering division (AG) totalled €2,809 billion, up +€46 billion over the quarter (or +1.7%), mainly due to a positive market effect and a good level of net inflows in the three business lines of Asset Management, Insurance and Wealth Management. Over the year, assets under management rose by +13.1%.

    Insurance activity (Crédit Agricole Assurances) was very strong with total premium income of €9.7 billion – a record level for a third quarter – up +38.9% compared to the third quarter of 2023, and up in all three segments: savings/retirement, property and casualty, and death & disability/creditor/group insurance. In total, overall premium income stood at €32.8 billion, up +18.2% compared to the first nine months of 2023.

    In Savings/Retirement, third-quarter premium income stood at €7.2 billion, up +56.4% compared to the third quarter of 2023. Business was driven by euro payment bonus campaigns in France, launched during the first quarter, which boosted gross euro inflows, as well as by a confirmed upturn in international business. The unit-linked rate accounted for 32.8% of gross inflows, down -7.5 percentage points compared to the third quarter of 2023. This decline is linked to the recovery in gross euro inflows and less favourable market conditions for unit-linked products, in particular the reduced attractiveness of unit-linked bond products. Net inflows totalled +€1.6 billion this quarter, on par with last quarter. This level is made up of positive net inflows from unit-linked contracts (+€0.9 billion) and also from euro funds (+€0.8 billion). In total, Savings/Retirement premium income reached €23.9 billion at the end of September, up +23.1% compared to the end of September 2023.

    Assets under management (savings, retirement and funeral insurance), which stood at €343.2 billion, continued to rise and reached their highest level ever. They were up +€19.0 billion over one year, or +5.8%, and +€12.9 billion since the beginning of the year, or +3.9%. The growth of assets under management was supported by a positive market effect and positive net inflows. Unit-linked contracts reached 29.9% of assets under management, up +2.3 percentage points over one year and +1.0 percentage point compared to the end of December 2023.

    In property and casualty insurance, premium income stood at €1.2 billion in the third quarter of 2024, up +9.2%25 compared to the third quarter of 2023. This growth was driven by volume and price effects. Indeed, at the end of September 2024, the portfolio stood at nearly 16.6 million26 contracts, up +5.1% year-on-year. At the same time, the average premium was up, benefiting from rate revisions in addition to changes in the product mix.  Lastly, the combined ratio at the end of September 2024 stood at 95.5%27, a deterioration of +0.3 percentage point year-on-year due to the unfavourable impact of discounting. In total, at the end of September 2024, premium income stood at €4.9 billion, an increase of +7.8% compared to the first nine months of 2023.

    In death & disability/creditor/group insurance, premium income for the third quarter of 2024 stood at €1.3 billion, up +2.2% compared to the third quarter of 2023. Creditor insurance premium income rose by +1.6% compared to the third quarter of 2023, thanks to an upturn in consumer finance and good performance in real estate. Death and disability was up +3.5% compared to the third quarter of 2023, mainly driven by group insurance, which posted an increase of +9.5%. In group insurance, an agreement was signed with Industries Electriques et Gazières in October 2024, with effect from the second half of 2025. In total, at the end of September, premium income from personal protection stood at €4.0 billion, an increase of +5.7% compared to the first nine months of 2023.

    In Asset Management (Amundi), Amundi’s assets under management saw a +11.1% increase year-on-year at 30 September 2024 and a +1.6% increase over the quarter to €2,192 billion, an all-time high. The +€35.4 billion increase in assets under management over the quarter was due to a positive market and foreign exchange impact of +€32.5 billion and positive net inflows of +€2.9 billion.

    This quarter’s net inflows include the exit from a mandate worth €11.6 billion with a European insurer, which was not generating much revenue. Adjusted for this outflow, net inflows for the quarter stood at +€14.4 billion, including +€9.1 billion in medium- and long-term assets28, driven by active management and ETFs. Structured products and real and alternative assets also recorded positive inflows, while treasury products28 were stable. Lastly, the JVs continued their solid commercial momentum, with net inflows of +€5.3 billion, reflecting a positive contribution from India and South Korea.

    By customer segment, Retail inflows (+€6.3 billion in the third quarter of 2024) were driven by the excellent momentum of third-party distributors (+€6.8 billion), across all regions and with good diversification of inflows by asset class. Excluding the loss of the insurance mandate mentioned above, the Institutional segment recorded very positive inflows in MLT assets across all segments, in particular Institutional and Sovereign, and on mandates from insurers in the Crédit Agricole Groupe and the Société Générale group, thanks to the continued recovery in the euro-denominated life insurance policies market in France during the quarter. Treasury products, on the other hand, experienced sharp seasonal outflows in this segment.

    In Wealth Management, total assets under management (CA Indosuez Wealth Management and LCL Private Banking) amounted to €274 billion at the end of September 2024, and were up +2.7% compared to June 2024 and +46.9% compared to September 2023.

    Indosuez Wealth Management had assets under management of €209.2 billion29 at the end of September, up +2.1%, or +€4.2 billion, compared to the end of June 2024 due to a positive market effect of +€2.5 billion and good level of activity with positive net inflows of +€1.8 billion, driven in particular by Switzerland and Asia. The quarter also saw Degroof Petercam funds begin to be marketed to Indosuez clients. Compared with the end of September 2023, assets under management were up by +€84.3 billion (or +67.5%), taking into account a scope effect of €69 billion (integration of Degroof Petercam in June 2024), a positive market effect and a good level of net inflows.

    In LCL’s Private Banking division, assets under management at the end of September totalled €64.8 billion, up by +€1.0 billion or +1.5% compared to the end of June 2024, thanks to a positive market effect and positive net inflows. Compared with the end of September 2023, assets under management were up by +€3.2 billion (or +5.3%), mainly due to a positive market effect, and also to positive net inflows.

    Results of the Asset Gathering division

    In the third quarter of 2024, AG generated €1,870 million in revenues, up +12.9% compared to the third quarter of 2023. Expenses rose by +20.9% to -€868 million. Thus, the cost/income ratio stood at 46.4%, up +3.0 percentage points compared to the third quarter of 2023. Gross operating income stood at €1,002 million, up +6.9% compared to the third quarter of 2023. Taxes stood at -€157 million, compared with -€221 million at the end of September 2023 (down -29.1%). The net income Group share of AG stood at €728 million, up +17.1% compared to the third quarter of 2023.

    At the end of September 2024, AG generated revenues of €5,603 million, up +9.1% compared to the end of September 2023. The increase is explained by a very high level of revenues in all three business lines: Insurance, Asset Management and Wealth Management. Costs excluding SRF increased +13.4%. As a result, the cost/income ratio excluding SRF stood at 43.5%, up +1.6 percentage points compared to the end of September 2023. Gross operating income stood at €3,168 million, an increase of +6.3% compared to the end of September 2023. Taxes stood at -€659 million, compared with -€699 million at the end of September 2023 (down -5.7%). The net income Group share of AG stood at €2,180 million, up +9.3% compared to the first nine months of 2023. Net income Group share increased between the first nine months of 2023 and the first nine months of 2024 in Asset Management (+10.2%) and the Insurance business lines (+11.3%), but was down in Wealth Management (-18.9%).

    At the end of September 2024, the Asset Gathering division contributed by 37% to the underlying net income Group share of the Crédit Agricole S.A. core businesses (excluding Corporate Centre division) and 27% to underlying revenues excluding the Corporate Centre division.

    As at 30 September 2024, equity allocated to the division amounted to €12.6 billion, including €10.4 billion for Insurance, €1.3 billion for Asset Management, and €0.8 billion for Wealth Management. The division’s risk-weighted assets amounted to €58.7 billion, including €35.7 billion for Insurance, €14.1 billion for Asset Management and €8.9 billion for Wealth Management.

    The underlying RoNE (return on normalised equity) stood at 27.1% for the first nine months of 2024.

    Insurance results

    In the third quarter of 2024, insurance revenues amounted to €635 million, down -1.2% compared to the third quarter of 2023. This includes €418 million from savings/retirement30, €117 million from personal protection31 and €40 million from property and casualty insurance32. Against a backdrop of increased business activity, the decline in revenues is explained in particular by the change in Property & Casualty claims, which were low in the third quarter of 2023 and higher in the third quarter of 2024, particularly for crop insurance, as well as by an unfavourable effect linked to the replacement of AT1 debt (for which the expense was recorded as minority interests) by Tier 2 debt (the cost of which is deducted from revenues).

    The contractual service margin (CSM) stood at €24.9 billion, up +4.5% since 31 December 2023. In the first nine months of 2024, the impact of the stock revaluation was positive, and the impact of new business exceeded the CSM allocation.

    Non-attributable expenses for the quarter stood at €85 million, up +5.1% over the third quarter of 2023. Gross operating income stood at €550 million, down -2.1% compared to the third quarter of 2023. Taxes stood at -€51 million, compared with -€131 million for the third quarter of 2023. This decline is due to a re-estimation of the tax rate including the impact of reduced-tax disposals of equity interests and the revaluation of securities at fair value, which took place during the quarter. Net income Group share stood at €478 million, up +16.2% compared to the third quarter of 2023.

    Revenues from insurance in the first nine months of 2024 came to €2,130 million, up +5.4% compared to the total at the end of September 2023. Non-attributable expenses came to €264 million, i.e. an increase of +11.4%. The cost/income ratio stood at 12.4%, below the target ceiling of 15% set by the Medium-Term Plan. Gross operating income stood at €1,866 million, up +4.6% compared to the first nine months of 2023. The tax charge stood at -€354 million, below the September 2023 level of -€411 million. Net income Group share amounted to €1,466 million, up +11.3% compared to the first nine months of 2023.

    Insurance contributed by 25% to the underlying net income Group share of the Crédit Agricole S.A. core businesses (excluding the Corporate Centre division) at the end of September 2024 and by 10% to their underlying revenues.

    Asset Management results

    In the third quarter of 2024, revenues amounted to €838 million, showing double-digit growth (+10.3% compared to the third quarter of 2023). The +9.2% increase in management fee and commission income compared to the third quarter of 2023 reflects the good level of activity and the increase in average assets under management excluding JVs (which increased by +8.6% over the same period, and by +1.2% between the second and third quarter). Performance fees increased by +€10 million compared with the third quarter of 2023, but there were fewer crystallisation dates in the third quarter than in the second or fourth quarters. Amundi Technology’s revenues increased by +41.8% compared to the third quarter of 2023. Financial revenues were down by -10.6% compared to third quarter of 2023. Operating expenses stood at -€466 million, up +7.5% mainly due to the consolidation of Alpha Associates, accelerated investment and the impact of revenue growth on variable compensation. The jaws effect was positive over the quarter. The cost/income ratio thus stood at 55.6%, an improvement year-on-year (-1.5 percentage point). Gross operating income increased by +14.1% compared to the third quarter of 2023. The contribution from equity-accounted entities, comprising the contribution from Amundi’s Asian joint ventures, stood at €33 million, up +36.4% from the third quarter of 2023, driven mainly by the strong growth of the contribution from SBI MF in India. The income tax charge stood at -€92 million, up +14.9%. Net income before non-controlling interests was €312 million, up +16.4% compared to the total at the end of September 2023. Net income Group share stood at €208 million, up +16.8% compared to the third quarter of 2023.

    In the first nine months of 2024, revenues rose by +7.2% in asset management, reflecting sustained growth in management fee and commission income and a sharp increase in Amundi Technology revenues (€54m, +28.2%) and net financial income. Performance fees were down slightly (-2.0%). Operating expenses excluding SRF increased by +6.3%. The cost/income ratio excluding SRF was 55.3%, stable compared to the total at the end of September 2023. As a result, gross operating income was up +8.8% compared to the first nine months of 2023. The net income of equity-accounted entities increased by +28.4%. All in all, net income Group share for the half-year stood at €623 million, an increase of +10.2%.

    Asset management contributed 10% to the underlying net income Group share of Crédit Agricole S.A.’s core businesses (excluding the Corporate Centre division) at end September 2024 and by 12% to their underlying revenues.

    At 30 September 2024, equity allocated to the Asset Management business line amounted to €1.3 billion, while risk-weighted assets totalled €14.1 billion.

    Wealth Management results33

    Revenues of Wealth Management stood at €397 million in the third quarter of 2024, up +56.6% compared to the third quarter of 2023. Revenues benefited from the impact of the integration of Degroof Petercam in June 2024; excluding this effect, they were supported by the good momentum of management fee and commission income, which offset the erosion of interest revenues. Expenses totalled -€317 million, up +55.5% compared to the third quarter of 2023, due to the impact of the integration of Degroof Petercam in June 202434 and integration costs of -€8 million in the third quarter. Restated for these impacts, growth in expenses is stable (+0.2% compared to the third quarter of 2023). The cost/income ratio in the third quarter of 2024 stood at 79.9%, down -0.6 percentage points compared to the third quarter of 2023. Gross operating income stood at €80 million, up +61.4% compared to the third quarter of 2023. Cost of risk was -€11 million in the third quarter of 2024, including the recognition of litigations and provisions for various cases. Net income on other assets stood at -€3 million in the third quarter of 2024, corresponding to the Degroof Petercam acquisition costs, restated as specific items. Net income Group share amounted to €42 million, up +30.6% compared to the third quarter of 2023.

    In the first nine months of 2024, Wealth Management’s revenues rose by +24.7% compared to the end of September 2023, notably benefiting from the integration of Degroof Petercam in June 2024 to reach €967 million. Expenses excluding SRF rose by +29.3% due to the impact of the integration of Degroof Petercam in June 2024 and the €14 million in integration costs. Restated for these impacts, growth in expenses is under control, increasing by +3.6% compared to the first nine months of 2023, due in particular to an unfavourable base effect in 2023. Gross operating income thus rose by +10.0% to €181 million. The cost of risk was -€12 million at the end of September 2024 (it was +€1 million at the end of September 2023). Net income on other assets stood at -€23 million at the end of September 2024, corresponding to the Degroof Petercam acquisition costs, restated as specific items. Net income Group share stood at €91 million for the first nine months of 2024, down -18.9% compared to the first nine months of 2023, but up +4.5% after restatement for integration and acquisition costs.

    Wealth Management contributed 2% of Crédit Agricole S.A.’s business lines underlying net income Group share. (excluding the Corporate Centre division) at end September 2024 and by 5% to their underlying revenues.

    At 30 September 2024, equity allocated to Wealth Management was €0.8 billion and risk-weighted assets totalled €8.9 billion.

    Activity of the Large Customers division

    Corporate and Investment Banking (CIB) once again posted a very good performance in the third quarter of 2024 (best third quarter and best year-to-date in terms of both revenues and results). Asset servicing also recorded strong business momentum during the period.

    CIB third-quarter underlying revenues rose sharply to €1,528 million, an increase of +8.0% compared to the third quarter of 2023, driven by growth in its two business lines. Revenues from Financing activities were up +7.2% compared to the third quarter of 2023, at €809 million. This was mainly due to the excellent performance of Commercial Banking (+9.5% compared to the third quarter of 2023), driven by the development of Corporate activities, especially in the Telecom sector, and a good level of revenues from asset financing and project financing. Capital Markets and Investment Banking also reported revenue growth of +9.0% compared to the third quarter of 2023, at €719 million, driven by the continued high level of performance of Capital Markets (+6.2% compared to the third quarter of 2023 for FICC) and the good level of activity in Investment Banking, (+22.8% compared to the third quarter of 2023), confirming the trend observed at the end of the first half of 2024.

    Financing activities thus confirmed its leading position in syndicated loans (#2 in France35 and #2 in EMEA35). Crédit Agricole CIB reaffirmed its strong position in bond issues (#3 All bonds in EUR Worldwide35) and was ranked #2 in Green, Social & Sustainable bonds in EUR36. Average regulatory VaR stood at €10.1 million in the third quarter of 2024, unchanged from the second quarter of 2024 when it was €10.1 million. It remained at a level that reflected prudent risk management.

    In addition, the third quarter of 2024 saw the continued migration of ISB (formerly RBC Investor Services in Europe) customer portfolios to CACEIS platforms, following the effective merger of the legal entities with those of CACEIS on 31 May 2024. Customer migration is expected to continue until the end of 2024. As a reminder, ISB integration costs will be recorded during the year for an amount of around €80 million to €100 million, including €25.9 million in the third quarter of 2024, i.e. €70 million recorded in the first nine months of 2024.

    In the third quarter of 2024, solid customer business and market effects supported growth in assets over the year. Assets under custody increased by +1.9% at the end of September 2024 compared to the end of June 2024 and increased by +12.1% compared to the end of September 2023, to reach €5,061 billion. Assets under administration were down -1.2% over the quarter (planned exit of some ISB customers) and up +4.2% year-on-year, reaching €3,386 billion at the end of September 2024.

    Results of the Large Customers division

    In the third quarter of 2024, stated revenues of the Large Customers division once again reached a record level of €2,054 million, up +8.8% compared to the third quarter of 2023, buoyed by excellent performance in the Corporate and Investment Banking and Asset Servicing business lines. The division’s specific items this quarter had an impact of +€2.8 million on Corporate and Investment Banking and comprised the DVA, the issuer spread portion of the FVA and secured lending amounting to +€3.6 million, and loan book hedging totalling -€0.8 million. Operating expenses were up compared to the third quarter of 2023 (+8.8%), due, on the one hand, to IT investments and the development of the business lines’ activity and, on the other hand, to the recognition of ISB integration costs of -€25.9 million, restated as specific items. As a result, the division’s gross operating income was up +8.8% from the third quarter of 2023 to €814 million. The division recorded an overall net addition for cost of risk of -€19 million in the third quarter of 2024, compared with an addition of -€13 million in the third quarter of 2023. Stated pre-tax income totalled €800 million, an increase over the period (+8.2%). The tax charge was
    -€234 million. Lastly, stated Net income Group share reached €520 million in the third quarter of 2024, compared with stated income of €488 million in the third quarter of 2023. Underlying net income Group share came to €532 million in the third quarter of 2024, versus €488 million in the third quarter of 2023.

    Over the first nine months of 2024, stated revenues of the Large Customers division amounted to a record high of €6,543 million, i.e. +12.0% compared to the first nine months of 2023. Operating expenses excluding SRF rose +13.4% compared to the same period to -€3,298 million, largely related to employee expenses and IT investments, and including ISB integration costs of -€70 million. Gross operating income for the first nine months of 2024 totalled €2,802 million, representing an increase of +25.4% compared to the first nine months of 2023. Over the period, the cost of risk recorded a net addition of -€25 million, compared to an addition of -€81 million in the same period. The business line’s contribution to stated Net income Group share was €1,936 million, a strong increase of +30.3% compared to the first nine months of 2023. Underlying net income Group share came to €1,935 million in the first nine months of 2024, versus €1,520 million in the first nine months of 2023.

    The division contributed 33% to the underlying net income Group share of Crédit Agricole S.A.’s core businesses (excluding the Corporate Centre division) at end September 2024 and 31% to underlying revenues excluding the Corporate Centre.

    At 30 September 2024, the equity allocated to the division was €13.3 billion and its risk-weighted assets were €140.5 billion.

    Underlying RoNE (return on normalised equity) stood at 19.0% at the end of September 2024.

    Corporate and Investment Banking results

    In the third quarter of 2024, Corporate and Investment Banking stated revenues reached a record at €1,531 million, up +8.2% from the third quarter of 2023. The Corporate and Investment Banking division’s specific items this quarter had an impact of +€2.8 million and comprised the DVA, the issuer spread portion of the FVA, and secured lending amounting to +€3.6 million, and loan book hedging totalling -€0.8 million. Operating expenses rose by +7.2% to -€864 million, mainly due to IT investments and the development of business line activities. Gross operating income rose sharply by +9.5% compared to the third quarter of 2023, taking it to a high level of +€667 million. The cost/income ratio was 56.4%, a slight change of -0.5 percentage point over the period. The cost of risk recorded a limited net provision of -€14 million, stable compared to the third quarter of 2023. Lastly, pre-tax income in the third quarter of 2024 stood at €653 million, versus €596 million in the third quarter of 2023. The tax charge stood at -€195 million. Lastly, stated net income Group share rose sharply by +10.3% to €446 million in the third quarter of 2024.

    Over the first nine months of 2024, stated revenues rose by +7.6% compared to the excellent level recorded in the first nine months of 2023, to a record level of €4,995 million. The specific items over the period had an impact of +€52.2 million and comprised the DVA (the issuer spread portion of the FVA and secured lending) amounting to +€45.8 million, and loan book hedging totalling +€6.3 million. Operating expenses excluding SRF rose +5.1%, mainly due to variable compensation and investments in IT and employees to support the development of the business lines. Thus, gross operating income of €2,370 million was up sharply (+26.5% compared to the first nine months of 2023). The cost of risk recorded a net provision of -€7 million in the first nine months of 2024, compared to a net provision of -€80 million in the first nine months of 2023. The income tax charge stood at -€609 million, up +27.1%. Lastly, stated net income Group share stood at €1,715 million for the first nine months of 2024, an increase of +33.6% over the period, the highest historical level. Underlying Net income Group share stood at €1,677 million over the first nine months of 2024, versus €1,318 million over the same period in 2023.

    Risk-weighted assets at the end of September 2024 were down -€2.7 billion compared to the end of June 2024 at €128.6 billion, still well under control with business growth.

    Asset servicing results

    In the third quarter of 2024, the revenues of Asset Servicing were up +10.7% compared to the third quarter of 2023, standing at €523 million. This rise was driven in particular by high fee and commission income, itself driven by the increase in assets and by the favourable trend in NIM. Operating expenses rose by +12.8% to
    -€376 million, including -€4 million in scope effects linked to the consolidation of the remaining ISB entities and a -€25.8 million in ISB integration costs restated as specific items. Excluding these effects, the increase in expenses was +5.5% compared to the third quarter of 2023. As a result, gross operating income was up by +5.7% to €147 million in the third quarter of 2024. Thus, the cost/income ratio stood at 71.9%, up +1.3 percentage points. Excluding ISB integration costs and the consolidation of the remaining ISB entities, it stood at 66.2%, an improvement of 3.3 percentage points compared to the third quarter of 2023. The quarter also recorded +€6 million in income from equity-accounted entities. Net income thus totalled €109 million, down -10.8% compared to the third quarter of 2023. Adjusted for the €35 million share of non-controlling interests, the business line’s contribution to stated net income Group share totalled €74 million in the third quarter of 2024, down -11.7% compared to the third quarter of 2023. Excluding ISB integration costs, net income Group share was up +4.8% compared to the third quarter of 2023.

    Stated revenues for the first nine months of 2024 were up +28.7% compared to the same period in 2023, buoyed by the integration of ISB, strong commercial momentum and a favourable trend in the interest margin over the period. Expenses excluding SRF were up +39.2% and included a scope effect of -€207 million over the first six months of 2024 and -€70 million in ISB integration costs. Gross operating income was up +20.0% compared to the first nine months of 2023. The cost/income ratio stood at 72.1%, an improvement of 5.5 points compared to the third quarter of 2023. Net income thus rose by +10.1%. The overall contribution of the business line to net income Group share in the first nine months of 2024 was €221 million, a +9.3% increase compared to the first nine months of 2023.

    Specialised financial services activity

    Crédit Agricole Personal Finance & Mobility’s (CAPFM) commercial production totalled €11.6 billion in the third quarter of 2024, stable compared to the third quarter of 2023. The share of automotive financing37 in quarterly new business production stood at 50.6% this quarter. The average customer rate for production was down -24 basis points from the second quarter of 2024. CAPFM’s assets under management stood at €116.8 billion at the end of September 2024, up +5.2% compared to the end of September 2023, driven by all activities (Automotive +6,9%38; LCL and Regional Banks +5.6%; Other entities +3.3%). Lastly, consolidated outstandings totalled €68.9 billion at the end of September 2024, up +4.7% compared to the third quarter of 2023.

    CAPFM has announced a number of recent developments: a plan to acquire 50% of GAC Leasing; a pan-European partnership with GAC Motor International to entrust CA Auto Bank with the financing of vehicles made by Chinese manufacturer GAC; a partnership with FATEC to offer a fleet management service to its customers; and an agreement with EDF to ramp up the installation of electric charging stations in France.

    Crédit Agricole Leasing & Factoring (CAL&F) commercial production increased by +13.6% compared to the third quarter of 2023. It was driven by all business lines, and was particularly strong in property leasing and renewable energy financing. Property leasing continued to grow in France and abroad. Leasing outstandings rose +8.8% year-on-year, both in France (+6.7%) and internationally (+17.4%), to reach €20.1 billion at the end of September 2024 (of which €15.9 billion in France and €4.2 billion internationally). Commercial factoring production fell by -17% compared to the third quarter of 2023. As a reminder, the third quarter of 2023 was marked by record production in Germany. Factoring outstandings at the end of September 2024 were stable compared to the end of September 2023.

    On 31 October 2024, Crédit Agricole Leasing & Factoring announced that it had signed an agreement to acquire Merca Leasing in Germany.

    Specialised financial services’ results

    The revenues of Specialised Financial Services rose to €869 million in the third quarter of 2024, down slightly by -1.6% compared to the third quarter of 2023. Expenses stood at -€437 million, up +3.1% compared to the third quarter of 2023. The cost/income ratio stood at 48%, up +2.3 percentage points compared to the same period in 2023. Gross operating income thus stood at €433 million, down -5.9% compared to the third quarter of 2023. Cost of risk reached -€223 million, stable compared to the third quarter of 2023. Net income from equity-accounted entities rose significantly (x4.5 compared to the third quarter of 2023) to €23 million. Excluding the base effect39 related to the reorganisation of Mobility activities at CAPFM, the change was -20.7%. Net income on other assets stood at -€2 million, versus €57 million in the third quarter of 2023. Excluding the base effect39 related to the reorganisation of Mobility activities at CAPFM, the change was -52.5%. The division’s Net income Group share amounted to €172 million, down -15.6% compared to the same period in 2023, and down -7% excluding the base effect39.

    Over the first nine months of 2024, revenues for the Specialised Financial Services division fell by-4.1%, but rose by +7.8% excluding the base effect40 related to the reorganisation of Mobility activities at CAPFM, compared to the first nine months of 2023. This favourable trend was driven by a good performance in CAL&F (+8.5%) and by higher revenues for CAPFM excluding the base effect40 (+7,6%), benefiting from the scope effects linked to the strategic pivot around Mobility at CAPFM, which led to the 100% consolidation of Crédit Agricole Auto Bank from the second quarter of 2023 and of ALD and LeasePlan activities in six European countries, as well as the acquisition of a majority stake in the capital of Hiflow in the third quarter of 2023. Underlying costs excluding SRF increased by +8.9% compared to the first nine months of 2023. Expenses excluding SRF, the base effect40 and scope effects rose by +3.1%. The cost/income ratio stood at 51.2%, or +6.1 percentage points versus the same period in 2023; excluding the base effect40, the change was +1.3 percentage points. The cost of risk was down -4.9% compared to the first nine months of 2023, to -€653 million, and up +8.4% excluding the base effect40. This increase incorporated in particular the impact of scope effects. The contribution from equity-accounted entities was down -8.5% versus the same period in 2023, and down -35.9% excluding the base effect40, due to the full consolidation of Crédit Agricole Auto Bank in the second quarter of 2023, which was previously accounted for using the equity method. Net income on other assets amounted to -€3 million at the end of September 2024, compared to €81 million at the end of September 2023 (-€7 million excluding the base effect40). Net income Group share thus came to €502 million, down -21% compared to the first nine months of 2023, but up +5.4% excluding the base effect40 related to the reorganisation of Mobility activities at CAPFM.

    The business line contributed 8% to the underlying net income Group share of Crédit Agricole S.A.’s core businesses. (excluding the Corporate Centre division) at the end of September 2024 and 13% to underlying revenues excluding the Corporate Centre.

    At 30 September 2024, the equity allocated to the division was €6.8 billion and its risk-weighted assets were €71.8 billion.

    The underlying RoNE (return on normalised equity) stood at 9.0% for the first nine months of 2024.

    Personal Finance and Mobility results

    CAPFM revenues totalled €678 million in the third quarter of 2024, down -4.2% compared to the third quarter of 2023. The price effect remained negative in the third quarter of 2024 compared to the third quarter of 2023, but stabilised compared to the second quarter of 2024, thanks in particular to an improved production margin rate over the last few quarters (stable in the third quarter of 2024 compared to the second quarter of 2024, and up by +86 basis points compared to the third quarter of 2023). Expenses remained under control at -€338 million, up +2.4% compared to the same period in 2023. Gross operating income stood at €340 million, down -10%. The cost/income ratio stood at 49.8%, up +3.2 percentage points compared to the same period in 2023. The cost of risk stood at -€201 million, down -2.4% from the third quarter of 2023. The cost of risk/outstandings thus stood at 112 basis points41, an improvement of -16 basis points compared to the third quarter of 2023. The Non Performing Loans ratio was 4.5% at the end of June 2024, up +0.2 percentage point compared to the end of June 2024, while the coverage ratio reached 74.2%, down -1.6 percentage points compared to the end of June 2024. The contribution from equity-accounted entities rose sharply (x5.1) compared to the same period in 2023, and fell by -20.7% excluding the base effect related to the reorganisation of Mobility activities39. Net income on other assets amounted to -€2 million in the third quarter of 2024, compared to €57 million in the third quarter of 2023. Excluding the base effect39, net income on other assets of the third quarter of 203 amounted to -€4 million. As a result, net income Group share totalled €118 million in the third quarter of 2024, i.e. -20.9% compared to the same period the previous year. Excluding the base effect39, net income Group share was down -9.3%.

    In the first nine months of 2024, CAPFM’s revenues totalled €2,042 million, down -7.1% compared with the first nine months of 2023, but up +7.6% excluding the base effect related to the reorganisation of Mobility activities42. Revenues benefited from scope effects related to the strategic pivot around Mobility, leading to the full consolidation of Crédit Agricole Auto Bank from the second quarter of 2023 and the consolidation of the ALD and LeasePlan activities in six European countries, as well as the acquisition of a majority stake in the capital of Hiflow in the third quarter of 2023. Expenses excluding SRF stood at -€1,035 million, an increase of +9.9% on 2023. Expenses excluding SRF, excluding the base effect42 and scope effects, were up +2.2%. Gross operating income therefore came in at €1,007 million, which was a drop of -19% but an increase of +4.7% excluding the base effect42. The cost/income ratio stood at 50.7%, or +7.9 percentage points versus the same period in 2023. When restated for the base effect, the change was +2.1 percentage points. Cost of risk fell -7.3% compared with the first nine months of 2023 to -€591 million, but rose +6.8% when the base effect42 is excluded. This rise notably includes the impact of scope effects. The contribution from equity-accounted entities was down -5.4% versus the same period in 2023, and down -33.1% excluding the base effect42 related to the scope effects of Crédit Agricole Auto Bank, which was fully consolidated in the second quarter of 2023 having previously been accounted for using the equity method. Income on other assets fell -55.5%, or -63,4% excluding the base effect42. As a result, net income Group share stood at €349 million in the first nine months of 2024, i.e. -31.3% from the same period one year earlier. Excluding the base effect42, net income Group share was stable at -0.1% compared with the same period in 2023.

    Leasing & Factoring results

    CAL&F’s revenues totalled €192 million, up +8.5% compared with the third quarter of 2023. This increase was driven by all business lines and benefited from volume effects (increase in factored revenues and equipment leasing outstandings). Expenses remained under control with an increase of +4.8%, while the cost/income ratio stood at 51.6%, an improvement of -1.8 percentage points from the third quarter of 2023. Gross operating income rose +12.7% to €93 million, with a positive jaws effect of +3.7 percentage points. Cost of risk totalled -€22 million, up +25.1% compared with the same period in 2023, linked to economic conditions in the corporate market. Cost of risk/outstandings stood at 22 basis points41, down slightly from the third quarter of 2023. As a result, net income Group share was €54 million, down -1.8% compared with the third quarter of 2023.

    In the first nine months of 2024, revenues totalled €563 million, an increase of +8.5% compared with the first nine months of 2023. Costs excluding SRF increased by +5.7% to €298 million. Gross operating income rose sharply to €265 million, a +19.8% increase compared with the first nine months of 2023. The underlying cost/income ratio excluding SRF amounted to 53%, an improvement of -1.4 percentage points compared with the first nine months of 2023. Cost of risk was up compared with the same period of 2023 (+26.7%). The business line’s contribution to underlying net income Group share was €153 million, up +20.2% compared with the first nine months of 2023.

    Crédit Agricole S.A. Retail Banking activity

    Activity in Crédit Agricole S.A.’s Retail Banking business was solid during the quarter, with customer capture continuing at a good pace and an increasing number of customers taking out insurance policies. Home loan production in France is steadily recovering, while continuing to rise for corporate loans. Outside France, loan activity was dynamic.

    Retail banking activity in France

    In the third quarter of 2024, activity remained buoyant with the confirmed recovery in mortgage lending and the continued stabilisation of the mix of inflows.

    Gross customer capture for the quarter stood at 76,000 new customers and net customer capture came in at 9,700 customers. The equipment rate for car, multi-risk home, health, legal, all mobile phones or personal accident insurance rose by +0.3 percentage points to stand at 27.9% at end-September 2024.

    Loan production totalled €7.5 billion, representing a year-on-year increase of +11%. The third quarter of 2024 confirmed the recovery in home loan production (+17% compared to the third quarter of 2023 and +73% compared to the second quarter of 2023), boosted by the proactive pricing policy. The average production rate for home loans came to 3.38%, down -46 basis points from the second quarter of 2024 and -32 basis points year on year. The home loan stock rate improved by +5 basis points over the quarter and by +18 basis points year on year. The solid momentum continued in the corporate market (+16% year on year). Production for small businesses declined in a competitive market and challenging economic environment.

    Outstanding loans stood at €169 billion at end-September 2024, representing a quarter-on-quarter increase of +0.4% and a year-on-year increase of +0.5% (of which +0.6% for home loans, +0.7% for loans to small businesses, +1.0% for consumer finance and -0.1% for corporate loans). Customer assets totalled €253.3 billion at end-September 2024, up +5.1% year on year, driven by interest-earning deposits and off-balance sheet funds. Customer assets also edged up +0.6% during the quarter. This was accompanied by the continued stabilisation of demand deposit volumes (+0.4% compared with end-June 2024) in a still-uncertain environment, as well as term deposits (-2.9% compared with end-June 2024). Off-balance sheet deposits benefited from a positive year-on-year market effect across all segments and positive net inflows in life insurance.

    Retail banking activity in Italy

    In the third quarter of 2024, CA Italy posted a gross customer capture of 43,000, while the customer base grew by around 13,000 customers.

    Loan outstandings at CA Italy stood at €61.3 billion43 at end-September 2024, up +3.0% compared with end-September 2023. This was despite the downturn in the Italian market44, mostly in the retail segment, which posted an increase in outstandings of +3.6%. Loan production, buoyed by the solid momentum in all markets, rose 7.5% compared with the third quarter of 2023. Home loan production remained steady (+7% compared with the second quarter of 2024), despite a -12% year-on-year decline due to a base effect linked to the success of the promotional campaign which ran in the third quarter of 2023. The loan stock rate was down -17 basis points on the second quarter of 2024, in line with the general trend in Italian market rates.

    Customer assets at end-September 2024 totalled €117.4 billion, up +3.7% compared with end-September 2023; on-balance sheet deposits were relatively unchanged from the previous year at +0.4%, while the cost of inflows decreased. Lastly, off-balance sheet deposits rose +9.2%, benefiting from a market effect and positive net inflows.

    CA Italy’s equipment rate in car, multi-risk home, health, legal, all mobile phones or personal accident insurance increased to 20.0%, up 1.7 percentage points compared with the third quarter of 2023.

    International Retail Banking activity excluding Italy

    For International Retail Banking excluding Italy, loan outstandings were up +4.2% at current exchange rates at end-September 2024 compared with end-September 2023 (+6.7% at constant exchange rates). Customer assets rose slightly by +0.4% over the same period at current exchange rates (+8.1% at constant exchange rates).

    In Poland in particular, loan outstandings increased by +11.8% versus September 2023 (+3.6% at constant exchange rates) and customer assets by +14% (+5.5% at constant exchange rates), against a backdrop of fierce competition for deposits. Loan production in Poland also remained strong, rising +32.4% compared with the third quarter of 2023 at current exchange rates (up +26% at constant exchange rates).

    In Egypt, loan outstandings rose -18.3% between end-September 2024 and end-September 2023 (+34.6% at constant exchange rates). Over the same period, inflows fell by -36.6% but were still up +4% at constant exchange rates.

    The surplus of deposits over loans in Poland and Egypt amounted to €1.6 billion at 30 September 2024, and totalled €3.2 billion including Ukraine.

    French retail banking results

    In the third quarter of 2024, LCL’s revenues stood at €979 million, down -1.7% compared with the third quarter of 2023 due to a base effect related to the reversal of the provision for Home Purchase Saving Plans in the third quarter of 202345. Excluding this base effect, revenues grew by +3.7% as a result of both net interest margin and fee and commission income. Net interest margin, excluding the Home Purchase Saving Plan base effect45, rose +2.3%45 year on year, benefiting from positive exceptional items related to the revaluation of equity investments. In addition, the increase in the cost of funding continued to weigh on the net interest margin, partially offset by the positive impact of gradual loan repricing and the favourable impact of the contribution of macro-hedging (virtually unchanged year on year). Fee and commission income was up +5.1% compared with the third quarter of 2023, driven by all activities.

    Expenses rose +3.2% to stand at -€608 million. The increase for the period is mainly related to the increase in property expenses and IT costs. The cost/income ratio stood at 62.1%, a rise of +2.9 percentage points compared with the third quarter of 2023. Gross operating income was down -8.8%, to €371 million (up +4.5% excluding the Home Purchase Saving Plan base effect45).

    The cost of risk was up +17% compared with the third quarter of 2023 to -€82 million (including +€18 million in cost of risk on performing loans, -€94 million in proven risk, and -€5 million in other risks). This increase was mainly due to corporate specific files and to the consumer finance segment. The cost of risk/outstandings remained under control, at 23 basis points. The coverage ratio stood at 59.8% at end-September 2024 (-1 percentage point compared with end-June 2024). The Non Performing Loans ratio reached 2.1% at end-September 2024, stable compared with end-June 2024 (+0.1 percentage point). As a result, net income Group share decreased by -19.2% compared with the third quarter of 2024 (-6.2% excluding the Home Purchase Saving Plan base effect45).

    In the first nine months of 2024, LCL revenues totalled €2,912 million, a +0.7% increase compared with the first nine months of 2023. The net interest margin was slightly up (+0.5%), benefiting from gradual loan repricing and the positive impact of macro-hedging, in the context of rising refinancing and funding costs, and positive exceptional items in the second and third quarters of 2024 (positive valuation effects on equity investments). Fee and commission income was up +0.9% compared with the first nine months of 2023 (impacted by the base effect of Image cheque in 202346, particularly in the life insurance and payment instrument segments. Expenses excluding SRF rose +3.4% over the period as a result of the increase in staff and IT costs, partially offset by a one-off impact on taxation and a base effect related to end-of-career allowances. The cost/income ratio excluding SRF stood at 61.8% (+1.6 percentage points compared with the first nine months of 2023). Gross operating income grew slightly by +0.5% year on year. Cost of risk increased by +44.3%, impacted by the rise in proven risk from corporates and recent consumer finance production. All in all, the business line’s contribution to net income Group share stood at €607 million, down -9.8% (-5% excluding Home Purchase Saving Plan base effect)

    In the end, the business line contributed 10% to the underlying net income Group share of Crédit Agricole S.A.’s core businesses. (excluding the Corporate Centre division) in the first nine months of 2024 and 14% to underlying revenues excluding the Corporate Centre.

    At 30 September 2024, the equity allocated to the business line stood at €5.3 billion and risk-weighted assets amounted to €55.3 billion. LCL’s underlying RoNE (return on normalised equity) stood at 14.4% for the first nine months of 2024.

    International Retail Banking results47

    In the third quarter of 2024, revenues for International Retail Banking totalled €1,006 million, falling slightly by -1.8% (+1.2% at constant exchange rates) compared with the third quarter of 2023. Operating expenses were under control at €519 million, an increase of +3.1% (+4.4% at constant exchange rates) Gross operating income consequently totalled €486 million, down -6.5% (-2.1% at constant exchange rates) for the period. Cost of risk amounted to -€59 million, down -51.1% compared with the third quarter of 2023 (-50.1% at constant exchange rates).

    All in all, net income Group share for CA Italy, CA Egypt, CA Poland and CA Ukraine amounted to €194 million in the third quarter of 2024, up +13.9% (-12.9% at constant exchange rates). This included a negative impact of -€40 million following the change in the corporate income tax rate in Ukraine.

    For the first nine months of 2024, International Retail Banking revenues rose by +3.9% to €3,090 million (+0.6% at constant exchange rates). Expenses excluding SRF and DGS stood at -€1,522 million, an increase of 2.1% compared with the first nine months of 2023. Gross operating income totalled €1,510 million, up +4.6% (+1.1% at constant exchange rates). Cost of risk fell by -41.0% (-23.0% at constant exchange rates) to -€213 million compared with the first nine months of 2023. In the end, net income Group share for International Retail Banking came to €678 million, versus €600 million in the first nine months of 2023, and included a negative impact of around -€40 million following the change in corporate income tax rate in Ukraine.

    In the first nine months of 2024, International Retail Banking contributed 12% to the underlying net income Group share of Crédit Agricole S.A.’s core businesses (excluding the Corporate Centre) and 15% to underlying revenues excluding the Corporate Centre.

    As at 30 September 2024, the capital allocated to International Retail Banking was €4.4 billion and risk-weighted assets totalled €46.3 billion.

    Results in Italy

    In the third quarter of 2024, revenues for Crédit Agricole Italy amounted to €764 million, down -2.5% compared with the third quarter of 2023. Revenues were impacted by a -2.5% decline in net interest margin compared with the third quarter of 2023 but were boosted by fee and commission income from assets under management, which remained relatively unchanged at +0.7%. Operating expenses were stable at 0.9% compared with the third quarter of 2023.

    Cost of risk amounted to -€48 million in the third quarter of 2024, down -43.4% from the third quarter of 2023, and corresponded almost entirely to provisions for proven risk. Cost of risk/outstandings48 stood at 44 basis points, an improvement of 6 basis points compared with the second quarter of 2024. The Non Performing Loans ratio improved compared with the first quarter of 2024 to stand at 3.0%, while the coverage ratio was 73.6% (+1.2 percentage points compared with the second quarter of 2024). Net income Group share for CA Italy was €164 million, down -1.3% compared with the third quarter of 2023.

    In the first nine months of 2024, revenues for Crédit Agricole Italy rose slightly by +0.8% to €2,323 million. Expenses excluding SRF and DGS (deposit guarantee fund in Italy) were under control at €1,161 million, a slight decrease of -0.2% compared with the first nine months of 2023. Gross operating income stood at €1,105 million, a slight increase of +0.3% compared with the first nine months of 2023. Cost of risk amounted to -€170 million, down -27.2% compared with the first nine months of 2023. As a result, CA Italy’s net income Group share totalled €497 million, an increase of +4.4% compared with the first nine months of 2023.

    CA Italy’s underlying RoNE (return on normalised equity) was 22.6% at 30 September 2024.

    International Retail Banking results – excluding Italy

    In the third quarter of 2024, revenues for International Retail Banking excluding Italy totalled €242 million, up +0.4% (+14.8% at constant exchange rates) compared with the third quarter of 2023. Revenues in Poland were up +22.2% compared with the third quarter of 2023 (+16.1% at constant exchange rates), boosted by a higher net interest margin and a strong upwards trend in fee and commission income. Revenues in Egypt were down (-19.9% compared with the third quarter of 2023) due to foreign exchange rate movements (depreciation of the Egyptian pound), but were particularly buoyant at constant exchange rates (+32.7%), benefiting from a sharp increase in the interest margin. Operating expenses for International Retail Banking excluding Italy amounted to €122 million, up +11.0% compared with the third quarter of 2023 (+17.8% at constant exchange rates). Gross operating income amounted to €120 million, a decrease of -8.5% (+11.8% at constant exchange rates) compared with the third quarter of 2023. Cost of risk amounted to -€11 million, down -68.9% (-68.9% at constant exchange rates). Furthermore, at end-September 2024, the coverage ratio for loan outstandings remained high in Poland and Egypt, at 121% and 139% respectively. In Ukraine, the local coverage ratio remains prudent (335%). All in all, the contribution of International Retail Banking excluding Italy to net income Group share was €30 million, down 49.1% compared with the third quarter of 2023.

    In the first nine months of 2024, revenues for International Retail Banking excluding Italy totalled €767 million, up +14.3% (+25.0% at constant exchange rates) compared with the first nine months of 2023, driven by the increase in net interest margin. Operating expenses amounted to -€361 million, up +10.2% compared with the first nine months of 2023 (+12.8% at constant exchange rates). The cost/income ratio at end-September 2024 was 47.1% (an improvement of 1.8 points on the cost/income ratio at end-September 2023). Thanks to strong growth in revenues, gross operating income came to €406 million, up 18.3% (+38.4% at constant exchange rates) from the first nine months of 2023. Cost of risk amounted to -€43 million, down -66.4% (-65.8% at constant exchange rates) compared with the first nine months of 2023. All in all, International Retail Banking excluding Italy contributed €182 million to net income Group share.

    The underlying RoNE (return on normalised equity) of Other IRB (excluding CA Italy) stood at 33.0% at 30 September 2024.

    At 30 September 2024, the entire Retail Banking business line contributed 22% to the underlying net income Group share of Crédit Agricole S.A.’s core businesses (excluding the Corporate Centre division) and 29% to underlying revenues excluding the Corporate Centre.

    At 30 September 2024, the division’s equity amounted to €9.7 billion. Its risk-weighted assets totalled €101.6 billion.

    Corporate Centre results

    The net income Group share of the Corporate Centre was -€161 million in the third quarter of 2024, down -€106 million compared with the third quarter of 2023. The negative contribution of the Corporate Centre division can be analysed by distinguishing between the “structural” contribution (-€161 million) and other items (+€1 million).
    The contribution of the “structural” component (-€161 million) decreased by -€138 million compared with the third quarter of 2023 and can be broken down into three types of activity:

    • The activities and functions of the Corporate Centre of the Crédit Agricole S.A. Parent Company. This contribution amounted to -€140 million in the third quarter of 2024, down -€75 million, notably due to a base effect of -€171 million related to reversals of provisions for Home Purchase Saving Plans recorded in the third quarter of 2023.
    • The business lines that are not part of the core businesses, such as CACIF (private equity), CA Immobilier, CATE and BforBank (equity-accounted). They contributed -€28 million in the third quarter of 2024, down -€65 million from the third quarter of 2023. This was due to the unfavourable impact of the revaluation of Banco BPM securities for -€35 million (+€5 million in the third quarter of 2024, against +€40 million in the third quarter of 2023), as well as a deterioration in the portfolio which pushed up the cost of potential risk (stages 1 and 2), particularly on financing guaranteed by Foncaris49
    • Group support functions. Their contribution amounted to +€7 million this quarter (+€3 million compared with the third quarter of 2023).

    The contribution of “other items” was up +€32 million compared with the third quarter of 2023.
    The “internal margins” effect at the time of the consolidation of the insurance activity at the Crédit Agricole level was accounted for through the Corporate Centre. Over the quarter, the impact of internal margins was -€211 million in revenues and +€211 million in expenses.

    In the first nine months of 2024, underlying net income Group share of the Corporate Centre division was -€506 million, down -€131 million compared with the first nine months of 2023. The structural component contributed -€513 million and other items of the division recorded a positive contribution of +€7 million in the first nine months.
    The “structural” component contribution was down -€2 million compared with the first nine months of 2023. It can be broken down into three types of activities:

    • The activities and functions of the Corporate Centre of the Crédit Agricole S.A. Parent Company. This contribution amounted to -€767 million in the first nine months of 2024, down -€55 million compared with the first nine months of 2023, including a base effect of -€171 million related to the reversal of the provision for Home Purchase Saving Plans recorded in the third quarter of 2023;
    • Business lines not attached to the core businesses, such as CACIF (private equity), CA Immobilier and BforBank: their contribution, at +€234 million in the first nine months of 2024, was up on the first nine months of 2023 (+€46 million), primarily due to the end of the SRF building-up period (-€77 million in the first half of 2023), as well as the impact of the valuation and dividend of Banco BPM securities for +€99 million;
    • The Group’s support functions: their contribution for the first nine months of 2024 was +€20 million, up +€7 million compared with the first nine months of 2023.

    The contribution of “other items” was down -€129 million compared with the first nine months of 2023.

    At 30 September 2024, risk-weighted assets stood at €29.6 billion.

    Financial strength

    Crédit Agricole Group

    At 30 September 2024, the phased-in Common Equity Tier 1 (CET1) ratio of Crédit Agricole Group was 17.4%, an increase of +0.1 percentage point compared with end-June 2024. Therefore, the Crédit Agricole Group posted a substantial buffer of 7.6 percentage points between the level of its CET1 ratio and the 9.8% SREP requirement. The fully loaded CET1 ratio was 17.3%.

    During the third quarter 2024:

    • The CET1 ratio benefited from an impact of +25 basis points related to retained earnings.
    • Changes in risk-weighted assets related to business lines organic growth impacted the Group’s CET1 ratio by -27 basis points (see below).
    • The methodological and other effects have a favourable impact of +4 basis points and include the contribution of the capital increase reserved for employees and a favourable change in unrealised gains and/or losses.

    The phased-in Tier 1 ratio stood at 18.3%, while the phased-in total ratio was 21.0% at end-September 2024.

    The phased-in leverage ratio stood at 5.5%, remaining stable compared with end-June 2024, well above the regulatory requirement of 3.5%.

    Risk-weighted assets for the Crédit Agricole Group amounted to €636 billion, up +€8.2 billion compared with 30 June 2024. The change can be broken down by business line as follows: Retail Banking +€7.3 billion, Asset Gathering +€3.2 billion (including +€3.1 billion in Insurance equity-accounted value), Specialised Financial Services +€0.3 billion, Large Customers -€2.3 billion (benefiting from favourable foreign exchange and regulatory impacts for Crédit Agricole CIB) and Corporate Centre -€0.2 billion.

    Maximum Distributable Amount (MDA and L-MDA) trigger thresholds

    The transposition of Basel regulations into European law (CRD) introduced a restriction mechanism for distribution that applies to dividends, AT1 instruments and variable compensation. The Maximum Distributable Amount (MDA, the maximum sum a bank is allowed to allocate to distributions) principle aims to place limitations on distributions in the event the latter were to result in non-compliance with combined capital buffer requirements.

    The distance to the MDA trigger is the lowest of the respective distances to the SREP requirements in CET1 capital, Tier 1 capital and total capital.

    At 30 September 2024, Crédit Agricole Group posted a buffer of 670 basis points above the MDA trigger, i.e. €43 billion in CET1 capital.

    Failure to comply with the leverage ratio buffer requirement would result in a restriction of distributions and the calculation of a maximum distributable amount (L-MDA).

    At 30 September 2024, Crédit Agricole Group posted a buffer of 196 basis points above the L-MDA trigger, i.e. €42 billion in Tier 1 capital. At the Crédit Agricole Group level, it is the distance to the L-MDA trigger that determines the distance to distribution restriction.

    At 30 September 2024, Crédit Agricole S.A. posted a buffer of 280 basis points above the MDA trigger, i.e. €11 billion in CET1 capital. Crédit Agricole S.A. is not subject to the L-MDA requirement.

    The issuance of a new AT1 instrument carried out by Crédit Agricole S.A. on 2 October 2024, for a nominal amount of US$1.25 billion, has a positive impact of 18 basis points on the Tier 1 and Total capital ratios of Crédit Agricole Group, as well as a positive impact of 5 basis points on its leverage ratio. This issuance also has a positive impact of 28 basis points on the Tier 1 and Total capital ratios of Crédit Agricole S.A. Taking this issuance into account in the solvency ratios at 30 September 2024, Crédit Agricole Group would post a buffer of 688 basis points above the MDA trigger, i.e. €44 billion in CET1 capital, and 201 basis points above the L-MDA trigger, i.e. €43 billion in Tier 1 capital. Crédit Agricole S.A. would post a buffer of 308 basis points above the MDA trigger, i.e. €12 billion in CET1 capital.

    TLAC

    Crédit Agricole Group must comply with the following TLAC ratio requirements at all times:

    • a TLAC ratio above 18% of risk-weighted assets (RWA), plus – in accordance with EU directive CRD 5 – a combined capital buffer requirement (including, for Crédit Agricole Group, a 2.5% capital conservation buffer, a 1% G-SIB buffer, the counter-cyclical buffer set at 0.77% and the 0.01% systemic risk buffer for CA Group at 30 September 2024). Considering the combined capital buffer requirement, Crédit Agricole Group must adhere to a TLAC ratio of above 22.3%;
    • a TLAC ratio of above 6.75% of the Leverage Ratio Exposure (LRE).

    The Crédit Agricole Group’s 2025 target is to maintain a TLAC ratio greater than or equal to 26% of RWA excluding eligible senior preferred debt.

    At 30 September 2024, Crédit Agricole Group’s TLAC ratio stood at 27.3% of RWA and 8.2% of leverage ratio exposure, excluding eligible senior preferred debt50, which is well above the requirements. The TLAC ratio, expressed as a percentage of risk weighted assets, increased by 20 basis points over the quarter, due to equity and eligible items increasing more rapidly than risk-weighted assets over the period. Expressed as a percentage of leverage ratio exposure (LRE), the TLAC ratio was up 20 basis points compared with June 2024.

    The Group thus has a TLAC ratio excluding eligible senior preferred debt that is 510 basis points higher, i.e. €32 billion, than the current requirement of 22.3% of RWA.

    At end-September 2024, €10.4 billion equivalent had been issued in the market (senior non-preferred and Tier 2 debt) as well as €1.25 billion of AT1. The amount of Crédit Agricole Group senior non-preferred securities taken into account in the calculation of the TLAC ratio was €35.2 billion.

    MREL

    The required minimum levels are set by decisions of resolution authorities and then communicated to each institution, then revised periodically. At 30 September 2024, Crédit Agricole Group has to meet a minimum total MREL requirement of:

    • 22.01% of RWA, plus – in accordance with EU directive CRD 5 – a combined capital buffer requirement (including, for Crédit Agricole Group, a 2.5% capital conservation buffer, a 1% G-SIB buffer, the counter-cyclical buffer set at 0.77% and the 0.01% systemic risk buffer for CA Group at 30 September 2024). Considering the combined capital buffer requirement, the Crédit Agricole Group has to meet to a total MREL ratio of above 26.3%;
    • 6.25% of the LRE.

    At 30 September 2024, the Crédit Agricole Group had a total MREL ratio of 32.9% of RWA and 9.8% of leverage exposure, well above the requirement.

    An additional subordination requirement (“subordinated MREL”) is also determined by the resolution authorities and expressed as a percentage of RWA and LRE. At 30 September 2024, this subordinated MREL requirement for the Crédit Agricole Group was:

    • 18.25% of RWA, plus a combined capital buffer requirement. Considering the combined capital buffer requirement, the Crédit Agricole Group has to meet to a subordinated MREL ratio of above 22.5%;
    • 6.25% of leverage exposure.

    At 30 September 2024, Crédit Agricole Group had a subordinated MREL ratio of 27.3% of RWA and 8.2% of leverage exposure, well above the requirement.

    The distance to the maximum distributable amount trigger related to MREL requirements (M-MDA) is the lowest of the respective distances to the MREL, subordinated MREL and TLAC requirements expressed in RWA.

    At 30 September 2024, Crédit Agricole Group had a buffer of 480 basis points above the M-MDA trigger, i.e. €31 billion in CET1 capital; the distance to the M-MDA trigger corresponds to the distance between the subordinated MREL ratio and the corresponding requirement.

    Crédit Agricole S.A.

    At 30 September 2024, Crédit Agricole S.A.’s solvency ratio was higher than the Medium-Term Plan target, with a phased-in Common Equity Tier 1 (CET1) ratio of 11.7%, up +0.1 percentage point from end-June 2024. Crédit Agricole S.A. therefore had a comfortable buffer of 3.1 percentage points between the level of its CET1 ratio and the 8.6% SREP requirement. The fully loaded CET1 ratio was 11.7%.

    During the third quarter 2024:

    • The CET1 ratio benefited this quarter from a positive impact of +19 basis points linked to retained earnings. This impact corresponds to net income Group share net of AT1 coupons (impact of +38 basis points) and of the distribution of 50% of earnings, i.e. a provision for dividends of 25 euro cents per share in third quarter 2024 (-19 basis points).
    • Changes in risk-weighted assets related to business line organic growth impacted the CET1 ratio by
      -14 basis points, of which -5 basis points in the Insurance business line (increase in the equity-accounted value over the quarter).
    • Methodological and other effects had a positive impact of +10 basis points and included the contribution of the capital increase reserved for employees and a favourable trend in unrealised gains and/or losses.

    The phased-in leverage ratio was 3.8% at end-September 2024, stable compared to end-June 2024 and above the 3% requirement.

    The phased-in Tier 1 ratio stood at 13.2% and the phased-in total ratio at 17.3% this quarter.

    Risk weighted assets for Crédit Agricole S.A. amounted to €402 billion at end of September 2024, up by +€3.1 billion compared to 30 June 2024. The change can be broken down by core business line as follows:

    • The Retail Banking divisions showed an increase of +€1.7 billion, particularly in France.
    • Asset Gathering posted an increase of +€3.2 billion, including +€3.1 billion in RWA for Insurance (increase in the equity-accounted value in the third quarter of 2024).
    • Specialised Financial Services remained stable at +€0.2 billion.
    • Large Customers recorded a decrease in risk-weighted assets of -€2.4 billion over the quarter, mainly as a result of foreign exchange and regulatory impacts in CIB.
    • The Corporate Centre divisions posted an increase in risk-weighted assets of +€0.4 billion.

    Liquidity and Funding

    Liquidity is measured at Crédit Agricole Group level.

    In order to provide simple, relevant and auditable information on the Group’s liquidity position, the banking cash balance sheet’s stable resources surplus is calculated quarterly.

    The banking cash balance sheet is derived from Crédit Agricole Group’s IFRS financial statements. It is based on the definition of a mapping table between the Group’s IFRS financial statements and the sections of the cash balance sheet and whose definition is commonly accepted in the marketplace. It relates to the banking scope, with insurance activities being managed in accordance with their own specific regulatory constraints.

    Further to the breakdown of the IFRS financial statements in the sections of the cash balance sheet, netting calculations are carried out. They relate to certain assets and liabilities that have a symmetrical impact in terms of liquidity risk. Deferred taxes, fair value impacts, collective impairments, short-selling transactions and other assets and liabilities were netted for a total of €68 billion at end-September 2024. Similarly, €157 billion in repos/reverse repos were eliminated insofar as these outstandings reflect the activity of the securities desk carrying out securities borrowing and lending operations that offset each other. Other nettings calculated in order to build the cash balance sheet – for an amount totalling €181 billion at end September 2024 – relate to derivatives, margin calls, adjustment/settlement/liaison accounts and to non-liquid securities held by Corporate and Investment banking (CIB) and are included in the “Customer-related trading assets” section.

    Note that deposits centralised with Caisse des Dépôts et Consignations are not netted in order to build the cash balance sheet; the amount of centralised deposits (€105 billion at end-September 2024) is booked to assets under “Customer-related trading assets” and to liabilities under “Customer-related funds”.

    In a final stage, other restatements reassign outstandings that accounting standards allocate to one section, when they are economically related to another. As such, Senior issuances placed through the banking networks as well as financing by the European Investment Bank, the Caisse des Dépôts et Consignations and other refinancing transactions of the same type backed by customer loans, which accounting standards would classify as “Medium long-term market funds”, are reclassified as “Customer-related funds”.

    Medium to long-term repurchase agreements are also included in “Long-term market funds”.

    Finally, the CIB’s counterparties that are banks with which we have a commercial relationship are considered as customers in the construction of the cash balance sheet.

    Standing at €1,719 billion at 30 September 2024, the Group’s banking cash balance sheet shows a surplus of stable funding resources over stable application of funds of €188 billion, down -€10 billion compared with end-June 2024.

    Total T-LTRO 3 outstandings for Crédit Agricole Group amounted to €0.7 billion at 30 September 2024.

    Furthermore, given the excess liquidity, the Group remained in a short-term lending position at 30 September 2024 (central bank deposits exceeding the amount of short-term net debt).

    Medium-to-long-term market resources were €263 billion at 30 September 2024, up slightly from end-June 2024.

    They included senior secured debt of €76 billion, senior preferred debt of €125 billion, senior non-preferred debt of €37 billion and Tier 2 securities amounting to €25 billion.

    The Group’s liquidity reserves, at market value and after haircuts, amounted to €466 billion at 30 September 2024, down -€12 billion compared to 30 June 2024.

    They covered short-term net debt more than two times over (excluding the replacements with Central Banks).

    The decrease in liquidity reserves was mainly due to:

    • The decrease in Central Bank deposits for -€15 billion;
    • The decrease in eligible claims to Central Bank (mainly due to the temporary removal of TRICP credit claims with an internal rating) for -€3 billion;
    • The increase in the securities portfolio for +€6 billion (+€3 billion of HQLA securities/+€3 billion of non-HQLA securities).

    Crédit Agricole Group also continued its efforts to maintain immediately available reserves (after recourse to ECB financing). Central bank eligible non-HQLA assets after haircuts amounted to €152 billion.

    Credit institutions are subject to a threshold for the LCR ratio, set at 100% on 1 January 2018.

    At 30 September 2024, the end of month LCR ratios were 147% for Crédit Agricole Group (representing a surplus of €97.7 billion) and 152% for Crédit Agricole S.A. (representing a surplus of €92.2 billion). They were higher than the Medium-Term Plan target (around 110%).

    In addition, the NSFR of Crédit Agricole Group and Crédit Agricole S.A. exceeded 100%, in accordance with the regulatory requirement applicable since 28 June 2021 and above the Medium-Term Plan target (>100%).

    The Group continues to follow a prudent policy as regards medium-to-long-term refinancing, with a very diversified access to markets in terms of investor base and products.

    At 30 September 2024, the Group’s main issuers raised the equivalent of €51 billion51,52in medium-to-long-term debt on the markets, 47% of which was issued by Crédit Agricole S.A. In particular, the following amounts are noted for the Group:

    • Crédit Agricole CIB issued €17.9 billion in structured format, including €1.2 billion in Green Bond format;
    • Crédit Agricole Personal Finance & Mobility issued €2 billion equivalent in EMTN issuances through Crédit Agricole Auto Bank (CAAB) and €0.7 billion equivalent in securitisations;
    • CA Italy issued two senior secured debt issuances for a total of €1.5 billion, of which €500 million in Green Bond format;
    • Crédit Agricole next bank (Switzerland) issued two tranches in senior secured format for a total of 200 million Swiss francs, of which 100 million Swiss francs in Green Bond format;
    • Crédit Agricole Assurances issued a €750 million Tier 2 10-year bullet subordinated bond and made a tender offer on two subordinated perpetual issuances (FR0012444750 & FR0012222297) for €788.5 million in September.

    The Group’s medium-to-long-term financing can be broken down into the following categories:

    • €9.0 billion in secured financing;
    • €22.0 billion in plain-vanilla unsecured financing;
    • €17.9 billion in structured financing;
    • €2.3 billion in long-term institutional deposits and CDs.

    In addition, €11.7 billion was raised through off-market issuances, split as follows:

    • €9.5 billion from banking networks (the Group’s retail banking or external networks);
    • €0.65 billion from supranational organisations or financial institutions;
    • €1.6 billion from national refinancing vehicles (including the credit institution CRH).

    At 30 September 2024, Crédit Agricole S.A. raised the equivalent of €24.1 billion on the market53,54representing 93% of its 2024 refinancing programme:

    The bank raised the equivalent of €24.1 billion, of which €7.3 billion in senior non-preferred debt and €3.1 billion in Tier 2 debt, as well as €7.2 billion in senior preferred debt and €6.5 billion in senior secured debt at end-September. The financing comprised a variety of formats and currencies, including:

    • €6.3 billion55;
    • 6.35 billion US dollars (€5.8 billion equivalent);
    • 1.1 billion pounds sterling (€1.3 billion equivalent);
    • 230 billion Japanese yen (€1.4 billion equivalent);
    • 0.8 billion Swiss francs (€0.8 billion equivalent);
    • 1.75 billion Australian dollars (€1.1 billion equivalent);
    • 7 billion renminbi (€0.9 billion equivalent).

    At end-September, Crédit Agricole S.A. had issued 64% of its funding plan in currencies other than the euro56,57.

    In addition, on 2 January 2024, Crédit Agricole S.A. issued a PerpNC6 AT1 bond for €1.25 billion at an initial rate of 6.5% and, on 24 September 2024, a PerpNC10 AT1 bond for $1.25 billion at an initial rate of 6.7%.

    Appendix 1 – Specific items, Crédit Agricole Group et Crédit Agricole S.A.

    Crédit Agricole Group – Specific items

      Q3-24 Q3-23 9M-24 9M-23
    €m Gross
    impact*
    Impact on
    Net income
    Gross
    impact*
    Impact on
    Net income
    Gross
    impact*
    Impact on
    Net income
    Gross
    impact*
    Impact on
    Net income
                     
    DVA (LC) 4 3 2 2 46 34 (21) (15)
    Loan portfolio hedges (LC) (1) (1) (2) (1) 6 5 (26) (19)
    Home Purchase Savings Plans (LCL) 52 38 1 1 52 38
    Home Purchase Savings Plans (CC) 230 171 (0) (0) 230 171
    Home Purchase Savings Plans (RB) 118 88 63 47 118 88
    Mobility activities reorganisation (SFS) 1 0 300 214
    Check Image Exchange penalty (CC) 42 42
    Check Image Exchange penalty (LCL) 21 21
    Check Image Exchange penalty (RB) 42 42
    Total impact on revenues 3 2 402 298 117 87 758 581
    Degroof Petercam integration costs (AG) (8) (6) (14) (10)
    ISB integration costs (LC) (26) (14) (70) (37)
    Mobility activities reorganisation (SFS) (18) (13)
    Total impact on operating expenses (34) (20) (84) (47) (18) (13)
    Mobility activities reorganisation (SFS) (85) (61)
    Provision for risk Ukraine (IRB) (20) (20)
    Total impact on cost of credit risk (20) (20) (85) (61)
    Mobility activities reorganisation (SFS) (26) (26) (39) (39)
    Total impact equity-accounted entities (26) (26) (39) (39)
    Degroof Petercam aquisition costs (AG) (3) (2) (23) (17)
    Mobility activities reorganisation (SFS) 61 45 89 57
    Total impact on Net income on other assets (3) (2) 61 45 (23) (17) 89 57
                     
    Total impact of specific items (34) (20) 436 317 (10) 3 705 525
    Asset gathering (11) (8) (37) (27)
    French Retail banking 170 126 65 48 233 189
    International Retail banking (20) (20)
    Specialised financial services 35 19 247 159
    Large customers (23) (12) 1 0 (18) 1 (47) (35)
    Corporate centre 230 171 (0) (0) 272 213
    * Impact before tax and before minority interests                

    Crédit Agricole S.A. – Specific Items

      Q3-24 Q3-23 9M-24 9M-23
    €m Gross
    impact*
    Impact on
    Net income
    Gross
    impact*
    Impact on
    Net income
    Gross
    impact*
    Impact on
    Net income
    Gross
    impact*
    Impact on
    Net income
                     
    DVA (LC) 4 3 2 2 46 33 (21) (15)
    Loan portfolio hedges (LC) (1) (1) (2) (1) 6 5 (26) (19)
    Home Purchase Savings Plans (FRB) 52 37 3 2 52 37
    Home Purchase Savings Plans (CC) 230 171 (2) (1) 230 171
    Mobility activities reorganisation (SFS) 1 0.5 300 214
    Check Image Exchange penalty (CC) 42 42
    Check Image Exchange penalty (LCL) 21 20
    Total impact on revenues 3 2 284 209 53 39 598 450
    Degroof Petercam integration costs (AG) (8) (6) (14) (10)
    ISB integration costs (LC) (26) (14) (70) (37)
    Mobility activities reorganisation (SFS) (18) (13)
    Total impact on operating expenses (34) (19) (84) (47) (18) (13)
    Provision for risk Ukraine (IRB) (20) (20)
    Mobility activities reorganisation (SFS) (85) (61)
    Total impact on cost of credit risk (20) (20) (85) (61)
                     
    Mobility activities reorganisation (SFS) (26) (26) (39) (39)
    Total impact equity-accounted entities (26) (26) (39) (39)
    Degroof Petercam aquisition costs (AG) (3) (2) (23) (17)
    Mobility activities reorganisation (SFS) 61 45 89 57
    Total impact Net income on other assets (3) (2) 61 45 (23) (17) 89 57
                     
    Total impact of specific items (34) (20) 318 227 (73) (45) 545 394
    Asset gathering (11) (8) (37) (26)
    French Retail banking 52 37 3 2 73 57
    International Retail banking (20) (20)
    Specialised financial services 35 19 247 159
    Large customers (23) (12) 1 0 (18) 1 (47) (34)
    Corporate centre 230 171 (2) (1) 272 213
    * Impact before tax and before minority interests          

    Appendix 2 – Crédit Agricole Group: income statement by business line

    Crédit Agricole Group – Results by business line, Q3-23 and Q3-24

      Q3-24 (stated)
    €m RB LCL IRB AG SFS LC CC Total
                     
    Revenues 3,266 979 1,029 1,857 869 2,054 (842) 9,213
    Operating expenses excl. SRF (2,409) (608) (539) (868) (437) (1,240) 511 (5,590)
    SRF
    Gross operating income 857 371 490 989 433 814 (331) 3,623
    Cost of risk (364) (82) (60) (13) (223) (19) (40) (801)
    Equity-accounted entities 0 33 23 6 61
    Net income on other assets 0 0 0 (3) (2) (0) (2) (5)
    Income before tax 493 290 430 1,006 231 801 (372) 2,877
    Tax (122) (66) (176) (156) (42) (234) 210 (587)
    Net income from discont’d or held-for-sale ope.
    Net income 371 224 254 850 189 566 (162) 2,291
    Non controlling interests (1) (0) (40) (128) (17) (35) 10 (211)
    Net income Group Share 371 223 214 722 172 531 (153) 2,080
      Q3-23 (stated)
    €m RB LCL IRB AG SFS LC CC Total
                     
    Revenues 3,345 996 1,046 1,657 883 1,888 (567) 9,249
    Operating expenses excl. SRF (2,328) (589) (522) (718) (424) (1,139) 454 (5,265)
    SRF
    Gross operating income 1,018 407 524 939 460 749 (113) 3,984
    Cost of risk (254) (70) (126) (0) (224) (13) (6) (693)
    Equity-accounted entities 1 1 24 5 6 0 37
    Net income on other assets 0 18 1 (5) 57 (2) (0) 69
    Income before tax 765 355 400 958 298 740 (119) 3,397
    Tax (178) (79) (118) (221) (77) (203) 65 (810)
    Net income from discont’d or held-for-sale ope. (0) 2 (0) 2
    Net income 587 277 284 737 220 537 (53) 2,588
    Non controlling interests (0) (0) (42) (110) (17) (39) 4 (204)
    Net income Group Share 587 277 242 628 204 497 (49) 2,384

    Crédit Agricole Group – Results by business line, 9M-24 et 9M-23

      9M-24 (stated)
    €m RB LCL IRB AG SFS LC CC Total
                     
    Revenues 9,834 2,912 3,161 5,596 2,605 6,544 (2,407) 28,244
    Operating expenses excl. SRF (7,453) (1,801) (1,637) (2,435) (1,333) (3,741) 1,535 (16,866)
    SRF
    Gross operating income 2,381 1,111 1,523 3,161 1,272 2,803 (872) 11,378
    Cost of risk (1,056) (295) (219) (18) (653) (25) (59) (2,324)
    Equity-accounted entities 7 94 83 20 203
    Net income on other assets 3 5 0 (23) (3) 2 (3) (19)
    Income before tax 1,335 820 1,305 3,214 699 2,800 (935) 9,238
    Tax (313) (185) (436) (658) (138) (717) 343 (2,104)
    Net income from discontinued or held-for-sale operations
    Net income 1,022 635 869 2,557 560 2,083 (592) 7,134
    Non controlling interests (1) (0) (129) (364) (59) (104) 15 (643)
    Net income Group Share 1,021 635 739 2,193 502 1,979 (577) 6,491
      9M-23 (stated)
    €m RB LCL IRB AG SFS LC CC Total
                     
    Revenues 10,032 2,891 3,040 5,144 2,717 5,844 (1,946) 27,722
    Operating expenses excl. SRF (7,217) (1,742) (1,542) (2,148) (1,224) (3,298) 1,389 (15,782)
    SRF (111) (44) (40) (6) (29) (312) (77) (620)
    Gross operating income 2,704 1,105 1,458 2,989 1,465 2,234 (634) 11,321
    Cost of risk (831) (205) (366) (1) (686) (81) (8) (2,179)
    Equity-accounted entities 9 1 73 90 17 190
    Net income on other assets 6 21 1 (5) 81 3 (1) 107
    Income before tax 1,887 921 1,095 3,057 950 2,173 (643) 9,438
    Tax (467) (217) (321) (696) (254) (561) 222 (2,293)
    Net income from discontinued or held-for-sale operations (0) 7 1 (0) 7
    Net income 1,421 704 781 2,361 696 1,612 (421) 7,153
    Non controlling interests (1) (0) (121) (343) (61) (93) (0) (619)
    Net income Group Share 1,420 704 660 2,018 635 1,519 (421) 6,534

    Appendix 3 – Crédit Agricole S.A.:   Results by business line

    Crédit Agricole S.A. – Results by business line, Q3-24 et Q3-23

      Q3-24 (stated)
    €m AG LC SFS FRB (LCL) IRB CC Total
                   
    Revenues 1,870 2,054 869 979 1,006 (290) 6,487
    Operating expenses excl. SRF (868) (1,240) (437) (608) (519) (17) (3,689)
    SRF
    Gross operating income 1,002 814 433 371 486 (307) 2,799
    Cost of risk (13) (19) (223) (82) (59) (37) (433)
    Equity-accounted entities 33 6 23 (19) 42
    Net income on other assets (3) (0) (2) 0 0 0 (4)
    Income before tax 1,019 800 231 290 427 (363) 2,404
    Tax (157) (234) (42) (66) (176) 199 (476)
    Net income from discontinued or held-for-sale operations
    Net income 862 566 189 224 252 (164) 1,928
    Non controlling interests (135) (46) (17) (10) (58) 4 (262)
    Net income Group Share 728 520 172 214 194 (161) 1,666
      Q3-23 (stated)
    €m AG LC SFS FRB (LCL) IRB CC Total
                   
    Revenues 1,656 1,888 883 996 1,024 (103) 6,343
    Operating expenses excl. SRF (718) (1,139) (424) (589) (504) (2) (3,376)
    SRF
    Gross operating income 937 748 460 407 520 (105) 2,967
    Cost of risk (0) (13) (224) (70) (121) (2) (429)
    Equity-accounted entities 24 6 5 1 (12) 23
    Net income on other assets (5) (2) 57 18 1 (0) 69
    Income before tax 956 739 298 355 401 (119) 2,630
    Tax (221) (203) (77) (79) (118) 65 (633)
    Net income from discontinued or held-for-sale operations (0) 2 2
    Net income 736 536 220 277 285 (55) 1,999
    Non controlling interests (114) (48) (17) (12) (60) 0 (251)
    Net income Group Share 621 488 204 264 225 (55) 1,748

    Crédit Agricole S.A. – Results by business line, 9M-24 et 9M-23

      9M-24 (stated)
    €m AG LC SFS FRB (LCL) IRB CC Total
                   
    Revenues 5,603 6,543 2,605 2,912 3,090 (665) 20,089
    Operating expenses excl. SRF (2,435) (3,741) (1,333) (1,801) (1,580) (88) (10,978)
    SRF
    Gross operating income 3,168 2,802 1,272 1,111 1,510 (752) 9,111
    Cost of risk (18) (25) (653) (295) (213) (53) (1,256)
    Equity-accounted entities 94 20 83 (65) 132
    Net income on other assets (23) 2 (3) 5 0 24 5
    Change in value of goodwill
    Income before tax 3,221 2,800 699 820 1,297 (846) 7,991
    Tax (659) (717) (138) (185) (435) 343 (1,790)
    Net income from discontinued or held-for-sale operations
    Net income 2,563 2,083 560 635 862 (503) 6,201
    Non controlling interests (382) (147) (59) (28) (184) (3) (803)
    Net income Group Share 2,180 1,936 502 607 678 (506) 5,397
      9M-23 (stated)
    €m AG LC SFS FRB (LCL) IRB CC Total
                   
    Revenues 5,133 5,844 2,717 2,891 2,975 (421) 19,140
    Operating expenses excl. SRF (2,148) (3,298) (1,224) (1,742) (1,491) (20) (9,922)
    SRF (6) (312) (29) (44) (40) (77) (509)
    Gross operating income 2,979 2,234 1,465 1,105 1,444 (519) 8,709
    Cost of risk (1) (81) (686) (205) (362) (2) (1,338)
    Equity-accounted entities 73 17 90 2 (45) 136
    Net income on other assets (5) 3 81 21 1 (0) 102
    Change in value of goodwill
    Income before tax 3,047 2,173 950 921 1,085 (566) 7,609
    Tax (699) (561) (254) (217) (320) 218 (1,832)
    Net income from discontinued or held-for-sale operations 1 (0) 7 7
    Net income 2,349 1,612 696 704 772 (348) 5,785
    Non controlling interests (353) (125) (61) (31) (172) (27) (771)
    Net income Group Share 1,996 1,486 635 673 600 (375) 5,014

    Appendix 4 – Data per share

    Crédit Agricole S.A. – Earnings p/share, net book value p/share and RoTE
    (€m)   Q3-2024 Q3-2023   9M-24 9M-23
                 
    Net income Group share – stated   1,666 1,748   5,397 5,014
    – Interests on AT1, including issuance costs, before tax   (130) (136)   (351) (371)
    – Foreign exchange impact on reimbursed AT1   (19)   (266)
    NIGS attributable to ordinary shares – stated [A] 1,517 1,612   4,780 4,643
    Average number shares in issue, excluding treasury shares (m) [B] 3,031 3,043   3,007 3,031
    Net earnings per share – stated [A]/[B] 0.50 € 0.53 €   1.59 € 1.53 €
    Underlying net income Group share (NIGS)   1,686 1,520   5,442 4,620
    Underlying NIGS attributable to ordinary shares [C] 1,537 1,384   4,825 4,249
    Net earnings per share – underlying [C]/[B] 0.51 € 0.46 €   1.60 € 1.40 €
                 
                 
    (€m)         30/09/2024 30/09/2023
    Shareholder’s equity Group share         71,386 69,416
    – AT1 issuances         (6,102) (7,235)
    – Unrealised gains and losses on OCI – Group share         1,042 1,644
    Net book value (NBV), not revaluated, attributable to ordin. sh. [D]       66,326 63,825
    – Goodwill & intangibles* – Group share         (17,778) (17,255)
    Tangible NBV (TNBV), not revaluated attrib. to ordinary sh. [E]       48,548 46,570
    Total shares in issue, excluding treasury shares (period end, m) [F]       3,040 3,052
    NBV per share , after deduction of dividend to pay (€) [D]/[F]       21.8 € 20.9 €
    TNBV per share, after deduction of dividend to pay (€) [G]=[E]/[F]       16.0 € 15.3 €
    * including goodwill in the equity-accounted entities            
                 
    (€m)         9M-24 9M-23
    Net income Group share – stated [K]       5,397 5,014
    Impairment of intangible assets [L]       0 0
    IFRIC [M]       -110 -542
    Stated NIGS annualised [N] = ([K]-[L]-[M])*2+[M]       7,233 6,866
    Interests on AT1, including issuance costs, before tax, foreign exchange impact, annualised [O]       -734 -495
    Stated result adjusted [P] = [N]+[O]       6,499 6,371
    Tangible NBV (TNBV), not revaluated attrib. to ord. sh. – avg *** (3) [J]       45,219 43,200
    Stated ROTE adjusted (%) = [P] / [J]       14.4% 14.7%
    Underlying Net income Group share [Q]       5,442 4,620
    Underlying NIGS annualised [R] = ([Q]-[M])*2+[M]       7,293 6,341
    Underlying NIGS adjusted [S] = [R]+[O]       6,559 5,846
    Underlying ROTE adjusted(%) = [S] / [J]       14.5% 13.5%
    *** including assumption of dividend for the current exercise         0.0%

    (1) Underlying: see appendixes for more details on specific items
    (2) Underlying ROTE calculated on the basis of an annualised underlying net income Group share and linearised IFRIC costs over the year
    (3) Average of the NTBV not revalued attributable to ordinary shares, calculated between 31/12/2023 and 30/09/2024 (line [E]), restated with an assumption of dividend for current exercises

    Alternative Performance Indicators58

    NBV Net Book Value (not revalued)
    The Net Book Value not revalued corresponds to the shareholders’ equity Group share from which the amount of the AT1 issues, the unrealised gains and/or losses on OCI Group share and the pay-out assumption on annual results have been deducted.

    NBV per share Net Book Value per share – NTBV Net Tangible Book Value per share
    One of the methods for calculating the value of a share. This represents the Net Book Value divided by the number of shares in issue at end of period, excluding treasury shares.

    Net Tangible Book Value per share represents the Net Book Value after deduction of intangible assets and goodwill, divided by the number of shares in issue at end of period, excluding treasury shares.

    EPS Earnings per Share
    This is the net income Group share, from which the AT1 coupon has been deducted, divided by the average number of shares in issue excluding treasury shares. It indicates the portion of profit attributable to each share (not the portion of earnings paid out to each shareholder, which is the dividend). It may decrease, assuming the net income Group share remains unchanged, if the number of shares increases.

    Cost/income ratio
    The cost/income ratio is calculated by dividing operating expenses by revenues, indicating the proportion of revenues needed to cover operating expenses.

    Cost of risk/outstandings
    Calculated by dividing the cost of credit risk (over four quarters on a rolling basis) by outstandings (over an average of the past four quarters, beginning of the period). It can also be calculated by dividing the annualised cost of credit risk for the quarter by outstandings at the beginning of the quarter. Similarly, the cost of risk for the period can be annualised and divided by the average outstandings at the beginning of the period.

    Since the first quarter of 2019, the outstandings taken into account are the customer outstandings, before allocations to provisions.

    The calculation method for the indicator is specified each time the indicator is used.

    Doubtful loan
    A doubtful loan is a loan in default. The debtor is considered to be in default when at least one of the following two conditions has been met:

    • a payment generally more than 90 days past due, unless specific circumstances point to the fact that the delay is due to reasons independent of the debtor’s financial situation.
    • the entity believes that the debtor is unlikely to settle its credit obligations unless it avails itself of certain measures such as enforcement of collateral security right.

    Impaired loan
    Loan which has been provisioned due to a risk of non-repayment.

    MREL
    The MREL (Minimum Requirement for Own Funds and Eligible Liabilities) ratio is defined in the European “Bank Recovery and Resolution Directive” (BRRD). This Directive establishes a framework for the resolution of banks throughout the European Union, with the aim to provide resolution authorities with shared instruments and powers to pre-emptively tackle banking crises, preserve financial stability and reduce taxpayers’ exposure to losses. Directive (EU) 2019/879 of 20 May 2019 known as “BRRD2” amended the BRRD and was transposed into French law by Order 2020-1636 of 21 December 2020.

    The MREL ratio corresponds to an own funds and eligible liabilities buffer required to absorb losses in the event of resolution. Under BRRD2, the MREL ratio is calculated as the amount of eligible capital and liabilities expressed as a percentage of risk weighted assets (RWA), as well as a leverage ratio exposure (LRE). Are eligible for the numerator of the total MREL ratio the Group’s regulatory capital, as well as eligible liabilities issued by the corporate centre and the Crédit Agricole network affiliated entities, i.e. subordinated notes, senior non-preferred debt instruments and certain senior preferred debt instruments with residual maturities of more than one year.

    Impaired (or non-performing) loan coverage ratio 
    This ratio divides the outstanding provisions by the impaired gross customer loans.

    Impaired (or non-performing) loan ratio 
    This ratio divides the impaired gross customer loans on an individual basis, before provisions, by the total gross customer loans.

    TLAC
    The Financial Stability Board (FSB) has defined the calculation of a ratio aimed at estimating the adequacy of the bail-in and recapitalisation capacity of Global Systemically Important Banks (G-SIBs). This Total Loss Absorbing Capacity (TLAC) ratio provides resolution authorities with the means to assess whether G-SIBs have sufficient bail-in and recapitalisation capacity before and during resolution. It applies to Global Systemically Important Banks, and therefore to Crédit Agricole Group. Agricole. The TLAC ratio requirement was transposed into European Union law via CRR2 and has been applicable since 27 June 2019.

    The Group’s regulatory capital as well as subordinated notes and eligible senior non-preferred debt with residual maturities of more than one year issued by Crédit Agricole S.A. are eligible for the numerator of the TLAC ratio.

    Net income Group share
    Net income/(loss) for the financial year (after corporate income tax). Equal to net income Group share, less the share attributable to non-controlling interests in fully consolidated subsidiaries.

    Underlying Net income Group share
    The underlying net income Group share represents the stated net income Group share from which specific items have been deducted (i.e., non-recurring or exceptional items) to facilitate the understanding of the company’s actual earnings.

    Net income Group share attributable to ordinary shares
    The net income Group share attributable to ordinary shares represents the net income Group share from which the AT1 coupon has been deducted, including issuance costs before tax.

    RoTE Return on Tangible Equity
    The RoTE (Return on Tangible Equity) measures the return on tangible capital by dividing the Net income Group share annualised by the Group’s NBV net of intangibles and goodwill. The annualised Net income Group share corresponds to the annualisation of the Net income Group share (Q1x4; H1x2; 9Mx4/3) excluding impairments of intangible assets and restating each period of the IFRIC impacts in order to linearise them over the year.

    Disclaimer

    The financial information on Crédit Agricole S.A. and Crédit Agricole Group for the third quarter and the first nine months of 2024 comprises this presentation and the attached appendices and press release which are available on the website: https://www.credit-agricole.com/en/finance/financial-publications.

    This presentation may include prospective information on the Group, supplied as information on trends. This data does not represent forecasts within the meaning of EU Delegated Act 2019/980 of 14 March 2019 (Chapter 1, article 1, d).

    This information was developed from scenarios based on a number of economic assumptions for a given competitive and regulatory environment. Therefore, these assumptions are by nature subject to random factors that could cause actual results to differ from projections. Likewise, the financial statements are based on estimates, particularly in calculating market value and asset impairment.

    Readers must take all these risk factors and uncertainties into consideration before making their own judgement.

    Applicable standards and comparability

    The figures presented for the nine-month period ending 30 September 2024 have been prepared in accordance with IFRS as adopted in the European Union and applicable at that date, and with prudential regulations currently in force. This financial information does not constitute a set of financial statements for an interim period as defined by IAS 34 “Interim Financial Reporting” and has not been audited.

    Note: The scopes of consolidation of the Crédit Agricole S.A. and Crédit Agricole Groups have not changed materially since the Crédit Agricole S.A. 2023 Universal Registration Document and its A.01 update (including all regulatory information about the Crédit Agricole Group) were filed with the AMF (the French Financial Markets Authority).

    The sum of values contained in the tables and analyses may differ slightly from the total reported due to rounding.

    At 30 June 2024, Indosuez Wealth Management had completed the acquisition of Degroof Petercam and now holds 65% of Banque Degroof Petercam alongside with CLdN Cobelfret, its historical shareholder, which would maintain a 20% stake in capital. As of 30 September 2024, Indosuez Wealth Management’s stake in Degroof Petercam has increased to 76%.

    At 30 June 2024, Amundi had completed the acquisition of Alpha Associates, an independent asset manager offering multi-management investment solutions in private assets.

    Financial Agenda

    05 February 2025        Publication of the 2024 fourth quarter and full year results
    30 April 2025                Publication of the 2025 first quarter results
    14 May 2025                General Meeting
    31 July 2025                Publication of the 2025 second quarter and the first half-year results
    30 October 2025                Publication of the 2025 third quarter and first nine months results

    Contacts

    CREDIT AGRICOLE PRESS CONTACTS

    CRÉDIT AGRICOLE S.A. INVESTOR RELATIONS CONTACTS

    Institutional investors + 33 1 43 23 04 31 investor.relations@credit-agricole-sa.fr
    Individual shareholders + 33 800 000 777 (freephone number – France only) relation@actionnaires.credit-agricole.com
         
    Cécile Mouton + 33 1 57 72 86 79 cecile.mouton@credit-agricole-sa.fr
     

    Equity investor relations:

       
    Jean-Yann Asseraf
    Fethi Azzoug
    + 33 1 57 72 23 81
    + 33 1 57 72 03 75
    jean-yann.asseraf@credit-agricole-sa.fr fethi.azzoug@credit-agricole-sa.fr
    Oriane Cante + 33 1 43 23 03 07 oriane.cante@credit-agricole-sa.fr
    Nicolas Ianna + 33 1 43 23 55 51 nicolas.ianna@credit-agricole-sa.fr
    Leila Mamou + 33 1 57 72 07 93 leila.mamou@credit-agricole-sa.fr
    Anna Pigoulevski + 33 1 43 23 40 59 anna.pigoulevski@credit-agricole-sa.fr
         
         
    Credit investor and rating agency relations:  
    Gwenaëlle Lereste + 33 1 57 72 57 84 gwenaelle.lereste@credit-agricole-sa.fr
    Florence Quintin de Kercadio + 33 1 43 23 25 32 florence.quintindekercadio@credit-agricole-sa.fr
         
         
         

    See all our press releases at: www.credit-agricole.com  


    1 Car, home, health, legal, all mobile phones or personal accident insurance.
    2 CA Auto Bank, automotive JVs and automotive activities of other entities
    3 50% reduction in the carbon footprint (tonnes of CO equivalent/€m invested) of its equity-listed and corporate bond investment portfolios and directly held property. (The previous target was a 25% reduction in the carbon footprint of its equity-listed and corporate bond investment portfolio in 2025 vs 2019.)

    4 Low-carbon energy outstandings made up of renewable energy produced by the clients of all Crédit Agricole Group entities, including nuclear energy outstandings for Crédit Agricole CIB.
    5 Crédit Agricole CIB green asset portfolio, in line with the eligibility criteria of the Group Green Bond Framework published in November 2023.
    6 The reorganisation of the Mobility activities of the CA Consumer Finance Group had a non-recurring impact in Q3 2023 due to the transfer of business assets, indemnities received and paid, the accounting treatment of the 100% consolidation of CA Auto Bank (formerly FCA Bank) and the reorganisation of the automotive financing activities within the CA Consumer Finance Group (particularly the review of application solutions).
    7 See Appendixes for more details on specific items.
    8 The cost of risk/outstandings (in basis points) on a four-quarter rolling basis is calculated on the cost of risk of the past four quarters divided by the average outstandings at the start of each of the four quarters
    9 The cost of risk/outstandings (in basis points) on an annualised basis is calculated on the cost of risk of the quarter multiplied by four and divided by the outstandings at the start of the quarter
    10 Average rate of loans to monthly production for July and August 2024.
    11 Equipment rate – Home-Car-Health policies, Legal, All Mobile/Portable or personal accident insurance
    12 SAS Rue La Boétie dividend paid annually in Q2
    13 Home Purchase Savings Plan base effect (reversal of the Home Purchase Savings Plan provision) in Q3-23 totalling +€118m in revenues and +€88m in net income Group share. 

    14 Underlying, excluding specific items.
    15 Scope effect of Degroof Petercam revenues: +€140 million in the third quarter of 2024.
    16 Scope effect in expenses in the third quarter of 2024: Degroof Petercam for -€104 million and miscellaneous others.
    17 Costs related to the integration of ISB (CACEIS): -€26 million in third quarter 2024 versus -€5 million in third quarter 2023; costs related to the integration of Degroof Petercam: -€8 million in third quarter 2024.

    18 Provisioning rate calculated with outstandings in Stage 3 as denominator, and the sum of the provisions recorded in Stages 1, 2 and 3 as numerator.
    19 The cost of risk/outstandings (in basis points) on a four-quarter rolling basis is calculated on the cost of risk of the past four quarters divided by the average outstandings at the start of each of the four quarters
    20 The cost of risk/outstandings (in basis points) on an annualised basis is calculated on the cost of risk of the quarter multiplied by four and divided by the outstandings at the start of the quarter
    21         See Appendixes for more details on specific items.
    22 SRF costs amounted to -€509 million over the first nine months of 2023

    23 See Appendixes for details on the calculation of the RoTE (return on tangible equity)
    24 The annualised underlying net income Group share corresponds to the annualisation of the underlying net income Group share (Q1x4; H1x2; 9Mx4/3) by restating each period for IFRIC impacts to linearise them over the year
    25 Property and casualty insurance premium income includes a scope effect linked to the first consolidation of CATU (a property and casualty insurance entity in Poland): Impact of +0.5% on growth in property and casualty insurance premium income (+8.7% change in premium income excluding CATU between the third quarter of 2023 and the third quarter of 2024); Impact of +2.0% on portfolio growth, i.e. an impact of 314,000 contracts (+3.1% growth excluding CATU between September 2023 and September 2024).

    26 Scope: property and casualty in France and abroad
    27 P&C combined ratio in France (Pacifica) including discounting and excluding undiscounting, net of reinsurance: (claims + operating expenses + fee and commission income) to gross earned premiums; the ratio is calculated for the first nine months of 2024. The net combined ratio excluding the effect of discounting for the first nine months of 2024 is 97.7% (-0.2 percentage point year-on-year).
    28 Excl. JVs
    29 Excluding assets under custody for institutional clients
    30 Amount of allocation of Contractual Service Margin (CSM) and Risk Adjustment (RA) including funeral guarantees
    31 Amount of allocation of CSM and RA
    32 Net of cost of reinsurance, excluding financial results
    33 Indosuez Wealth Management scope
    34 Degroof Petercam data for the quarter included in Wealth Management results: Revenues of €140m and expenses of -€104m (excluding integration costs partly borne by Degroof Petercam)

    35 Refinitiv LSEG
    36 Bloomberg in EUR
    37 CA Auto Bank, automotive JVs and auto activities of other entities
    38 CA Auto Bank and automotive JVs
    39 Base effect related to the reorganisation of Mobility activities in Q3-23: +€1m in revenues, -€26m in equity-accounted entities, +€61m in net income on other assets, -€16m in corporate income tax, i.e. +€19m in net income Group share
    40 Base effect related to the reorganisation of Mobility activities in 9M-23: +€300 million in revenues, -€18 million in expenses, -€85 million in cost of risk, -€39 million in equity-accounted entities, +€89 million in net income on other assets, -€89 million in corporate income tax, i.e. +€159 million in net income Group share.
    41 Cost of risk for the last four quarters as a proportion of the average outstandings at the beginning of the period for the last four quarters.
    42 Base effect related to the reorganisation of Mobility activities in 9M-23: +€300 million in revenues, -€18 million in expenses, -€85 million in cost of risk, -€39 million in equity-accounted entities, +€89 million in net income on other assets, -€89 million in corporate income tax, i.e. +€159 million in net income Group share.
    43 Net of POCI outstandings
    44 Source: Abi Monthly Outlook, July 2024: -1.9% June/June and -1.2% year to date for all loans
    45 Home Purchase Saving Plan base effect (reversal of the provision for Home Purchase Saving Plans) in Q2-23 of +€52 million in revenues and +€37 million in net income Group share.
    46 Reversal of provision for Cheque Image Exchange Provision of + €21m in Q2-23
    47 At 30 September 2024 this scope includes the entities CA Italy, CA Polska, CA Egypt and CA Ukraine.

    48 Over a rolling four quarter period.
    49 A credit institution that is a wholly owned subsidiary of Crédit Agricole S.A. Large credit exposures borne by the Regional Banks must be presented to Foncaris, which partially guarantees such exposures.
    50 As part of its annual resolvability assessment, Crédit Agricole Group has chosen to waive the possibility offered by Article 72ter(3) of the Capital Requirements Regulation (CRR) to use senior preferred debt for compliance with its TLAC requirements in 2024.
    51 Gross amount before buy-backs and amortisations
    52 Excl. AT1 issuances
    53 Gross amount before buy-backs and amortisations
    54 Excl. AT1 issuances
    55 Excl. senior secured debt
    56 Excl. senior secured debt
    57 Excl. AT1 issuances
    58 APMs are financial indicators not presented in the financial statements or defined in accounting standards but used in the context of financial communications, such as underlying net income Group share or RoTE. They are used to facilitate the understanding of the company’s actual performance. Each APM indicator is matched in its definition to accounting data.

    Attachment

    The MIL Network

  • MIL-OSI: OSB GROUP PLC – Q3 Trading Update

    Source: GlobeNewswire (MIL-OSI)

    LEI: 213800ZBKL9BHSL2K459

    OSB GROUP PLC: Trading update

    Published: 6.11.2024

    OSB GROUP PLC

    Q3 Trading update

    OSB GROUP PLC (OSBG or the Group), the specialist lending and retail savings group, today issues its trading update for the period from 1 July 2024 to date.  

    Key highlights for the period

    The Group maintained its lending discipline with organic originations of £0.9bn in the third quarter of 2024 (Q3 2023: £1.3bn), as demand in our core sub-segments remained in line with previous expectations. Underlying1 and statutory net loans increased by 2% in the nine months to 30 September to £26.3bn (31 December 2023: £25.7bn and £25.8bn, respectively). Our renewed focus on Commercial Mortgages, Bridging Finance and Asset Finance is progressing, with an increase in applications in each of these sub-segments received in the third quarter. We now expect underlying net loan book growth of slightly under 3% for 2024.

    Underlying net interest margin guidance is unchanged at 230bps–240bps for 2024 as higher yielding mortgages in the back book roll off to current prevailing spreads and as the market observes slightly elevated fixed term retail deposit pricing. The Group continues to evaluate customer behaviour in the reversion period throughout the fourth quarter and will assess this as part of the usual year-end process. The potential future impact of Precise Buy-to-Let customers spending less time on reversion will reduce significantly over the next two years as these mortgages reach maturity.

    The Group continues to focus on cost control with proactive actions to make its business-as-usual cost base more efficient. At the same time, we continue to invest in the digitalisation of our core platform and customer facing propositions. In October the Group launched the first product on its new savings platform to Kent Reliance customers and will expand the range of products available over the coming months. The expected underlying cost to income ratio remains at c.36% for 2024.

    Three months plus arrears balances increased by 10bps to 1.7% as at 30 September (30 June 2024: 1.6%) in line with management expectations as long-term fixed rate mortgages mature and transfer to higher prevailing rates. The Group’s secured loan book benefitted from a small impairment release in the third quarter as the Group adopted improved forward-looking macroeconomic scenarios.

    Capital and liquidity remain strong and the Group is reviewing the recently published Basel 3.1 capital standards which will be implemented on 1 January 2026. There remain areas of clarification and until these are finalised, our guidance on the impact for the Group at implementation is unchanged at slightly less than two percentage points on the Group’s CET1 ratio which stood at 16.2% at 30 June 2024. The Group has repurchased £32.1m worth of shares under the £50m repurchase programme announced in August.2

    Andy Golding, CEO of OSB GROUP PLC, said:

    “Looking forward, whilst challenges remain, there are signs of a gradual return of confidence in our core markets and we are seeing increased applications in our more cyclical businesses. The potential impact on the future plans of professional landlords due to the increase in stamp duty on second properties introduced following the recent budget is being monitored. We have a diversified loan book with proven capabilities in multi-property professional Buy-to-Let lending and specialist residential mortgages and continue to invest in our business to ensure it is fit for the future.”

    1. Underlying refers to results which exclude acquisition-related items arising from the Combination with CCFS
    2. As at market close on 5 November 2024

    Financial calendar for 2025*

    13 March 2025 2024 year end results
    30 April 2025 Q1 trading update
    8 May 2025 AGM
    20 August 2025 2025 half year results
    6 November 2025 Q3 trading update

    * All dates are subject to change

    Enquiries:

    OSB GROUP PLC

    Alastair Pate, Investor Relations        t: 01634 838 973

    Brunswick Group         

    Robin Wrench / Simone Selzer        t: 020 7404 5959

    About OSB GROUP PLC
    OneSavings Bank plc (OSB) began trading as a bank on 1 February 2011 and was admitted to the main market of the London Stock Exchange in June 2014 (OSB.L). OSB joined the FTSE 250 index in June 2015. On 4 October 2019, OSB acquired Charter Court Financial Services Group plc (CCFS) and its subsidiary businesses. On 30 November 2020, OSB GROUP PLC became the listed entity and holding company for the OSB Group. The Group provides specialist lending and retail savings and is authorised by the Prudential Regulation Authority, part of the Bank of England, and regulated by the Financial Conduct Authority and Prudential Regulation Authority. The Group reports under two segments, OneSavings Bank and Charter Court Financial Services.

    OneSavings Bank (OSB)
    OSB primarily targets market sub-sectors that offer high growth potential and attractive risk-adjusted returns in which it can take a leading position and where it has established expertise, platforms and capabilities. These include private rented sector Buy-to-Let, commercial and semi-commercial mortgages, residential development finance, bespoke and specialist residential lending, secured funding lines and asset finance.

    OSB originates mortgages via specialist brokers and independent financial advisers through its specialist brands including Kent Reliance for Intermediaries and InterBay Commercial. It is differentiated through its use of highly skilled, bespoke underwriting and efficient operating model.

    OSB is predominantly funded by retail savings originated through the long-established Kent Reliance name, which includes online as well as a network of branches in the Southeast of England. Diversification of funding is currently provided by securitisation programmes and the Bank of England’s Term Funding Scheme with additional incentives for SMEs.

    Charter Court Financial Services Group (CCFS)
    CCFS focuses on providing Buy-to-Let and specialist residential mortgages, mortgage servicing, administration and retail savings products. It operates through its brands: Precise and Charter Savings Bank.

    It is differentiated through risk management expertise and automated technology and systems, ensuring efficient processing, strong credit and collateral risk control and speed of product development and innovation. These factors have enabled strong balance sheet growth whilst maintaining high credit quality mortgage assets.

    CCFS is predominantly funded by retail savings originated through its Charter Savings Bank brand. Diversification of funding is currently provided by securitisation programmes and the Bank of England’s Term Funding Scheme with additional incentives for SMEs.

    Important disclaimer

    This document should be read in conjunction with any other documents or announcements distributed by OSB GROUP PLC (OSBG) through the Regulatory News Service (RNS). This document is not audited and contains certain forward-looking statements with respect to the business, strategy and plans of OSBG, its current goals, beliefs, intentions, strategies and expectations relating to its future financial condition, performance and results. Such forward-looking statements include, without limitation, those preceded by, followed by or that include the words ‘targets’, ‘believes’, ‘estimates’, ‘expects’, ‘aims’, ‘intends’, ‘will’, ‘may’, ‘anticipates’, ‘projects’, ‘plans’, ‘forecasts’, ‘outlook’, ‘likely’, ‘guidance’, ‘trends’, ‘future’, ‘would’, ‘could’, ‘should’ or similar expressions or negatives thereof but are not the exclusive means of identifying such statements. Statements that are not historical or current facts, including statements about OSBG’s, its directors’ and/or management’s beliefs and expectations, are forward-looking statements. By their nature, forward-looking statements involve risk and uncertainty because they relate to events and depend upon circumstances that may or may not occur in the future that could cause actual results or events to differ materially from those expressed or implied by the forward-looking statements. Factors that could cause actual business, strategy, plans and/or results (including but not limited to the payment of dividends) to differ materially from the plans, objectives, expectations, estimates and intentions expressed in such forward-looking statements made by OSBG or on its behalf include, but are not limited to: general economic and business conditions in the UK and internationally; market related trends and developments; fluctuations in exchange rates, stock markets, inflation, deflation, interest rates, energy prices and currencies; policies of the Bank of England, the European Central Bank and other G7 central banks; the ability to access sufficient sources of capital, liquidity and funding when required; changes to OSBG’s credit ratings; the ability to derive cost savings; changing demographic developments, and changing customer behaviour, including consumer spending, saving and borrowing habits; changes in customer preferences; changes to borrower or counterparty credit quality; instability in the global financial markets, including Eurozone instability, the potential for countries to exit the European Union (the EU) or the Eurozone, and the impact of any sovereign credit rating downgrade or other sovereign financial issues; technological changes and risks to cyber security; natural and other disasters, adverse weather and similar contingencies outside OSBG’s control; inadequate or failed internal or external processes, people and systems; terrorist acts and other acts of war (including, without limitation, the Russia-Ukraine war, the Israel-Hamas war and any continuation and escalation of such conflicts) or hostility and responses to those acts; the conflict in the Middle East; geopolitical events and diplomatic tensions; the impact of outbreaks, epidemics and pandemics or other such events; changes in laws, regulations, taxation, ESG reporting standards, accounting standards or practices, including as a result of the UK’s exit from the EU; regulatory capital or liquidity requirements and similar contingencies outside OSBG’s control; the policies and actions of governmental or regulatory authorities in the UK, the EU or elsewhere including the implementation and interpretation of key legislation and regulation; the ability to attract and retain senior management and other employees; the extent of any future impairment charges or write-downs caused by, but not limited to, depressed asset valuations, market disruptions and illiquid markets; market relating trends and developments; exposure to regulatory scrutiny, legal proceedings, regulatory investigations or complaints; changes in competition and pricing environments; the inability to hedge certain risks economically; the adequacy of loss reserves; the actions of competitors, including non-bank financial services and lending companies; the success of OSBG in managing the risks of the foregoing; and other risks inherent to the industries and markets in which OSBG operates.

    Accordingly, no reliance may be placed on any forward-looking statement. Neither OSBG, nor any of its directors, officers or employees provides any representation, warranty or assurance that any of these statements or forecasts will come to pass or that any forecast results will be achieved. Any forward-looking statements made in this document speak only as of the date they are made and it should not be assumed that they have been revised or updated in the light of new information of future events. Except as required by the Prudential Regulation Authority, the Financial Conduct Authority, the London Stock Exchange PLC or applicable law, OSBG expressly disclaims any obligation or undertaking to release publicly any updates or revisions to any forward-looking statements contained in this document to reflect any change in OSBG’s expectations with regard thereto or any change in events, conditions or circumstances on which any such statement is based. For additional information on possible risks to OSBG’s business, (which may cause actual results to differ materially from those expressed or implied in any forward-looking statement), please see the Risk review section in the OSBG Annual Report and Accounts 2023. Copies of this are available at www.osb.co.uk and on request from OSBG.

    Nothing in this document or any subsequent discussion of this document constitutes or forms part of a public offer under any applicable law or an offer or the solicitation of an offer to purchase or sell any securities or financial instruments. Nor does it constitute advice or a recommendation with respect to such securities or financial instruments, or any invitation or inducement to engage in investment activity under section 21 of the Financial Services and Markets Act 2000. Past performance cannot be relied on as a guide to future performance. Statements about historical performance must not be construed to indicate that future performance, share price or results in any future period will necessarily match or exceed those of any prior period. Nothing in this document is intended to be, or should be construed as, a profit forecast or estimate for any period.

    In regard to any information provided by third parties, neither OSBG nor any of its directors, officers or employees explicitly or implicitly guarantees that such information is exact, up to date, accurate, comprehensive or complete. In no event shall OSBG be liable for any use by any party of, for any decision made or action taken by any party in reliance upon, or for inaccuracies or errors in, or omission from, any third-party information contained herein. Moreover, in reproducing such information by any means, OSBG may introduce any changes it deems suitable, may omit partially or completely any aspect of the information from this document, and accepts no liability whatsoever for any resulting discrepancy.

    Liability arising from anything in this document shall be governed by English law, and neither OSBG nor any of its affiliates, advisors or representatives shall have any liability whatsoever (in negligence or otherwise) for any loss howsoever arising from any use of this document or its contents or otherwise arising in connection with this document. Nothing in this document shall exclude any liability under applicable laws that cannot be excluded in accordance with such laws.

    Certain figures contained in this document, including financial information, may have been subject to rounding adjustments and foreign exchange conversions. Accordingly, in certain instances, the sum or percentage change of the numbers contained in this document may not conform exactly to the total figure given.

    Non-IFRS performance measures

    OSBG believes that any non-IFRS performance measures included in this document provide a more consistent basis for comparing the business’ performance between financial periods and provide more detail concerning the elements of performance which OSBG is most directly able to influence or which are relevant for an assessment of OSBG. They also reflect an important aspect of the way in which operating targets are defined and performance is monitored by the Board. However, any non-IFRS performance measures in this document are not a substitute for IFRS measures and readers should consider the IFRS measures as well. For further details, refer to the Alternative Performance Measures section in the OSBG Annual Report and Accounts 2023. Copies of this are available at www.osb.co.uk and on request from OSBG.

    The MIL Network

  • MIL-OSI Economics: Frank Elderson: The first decade of European supervision: taking stock and looking ahead

    Source: European Central Bank

    Keynote speech by Frank Elderson, Member of the Executive Board of the ECB and Vice-Chair of the Supervisory Board of the ECB at the “10 Years of SSM – Looking back and looking forward” conference organised by the European Banking Institute and the Hessisches Ministerium für Wissenschaft und Kunst

    Frankfurt am Main, 4 November 2024

    Introduction

    Thank you for your kind invitation. It’s a pleasure to be with you this afternoon to reflect on the first decade of European banking supervision and, most importantly, to take a look at the path ahead of us.

    On this day ten years ago, the morning might have seemed just like a typical November morning in Frankfurt’s Bankenviertel: a rainy autumn day, with people heading to their offices armed with umbrellas, wearing heavy coats.

    But that day ten years ago was anything but typical.

    Because it was the first time European supervisory teams got together and started work on an important task: making sure the banking system is safe and sound on behalf of European citizens.

    At the time, some argued that integrating a fragmented system of supervision was either impossible or would take forever. Well, those pioneer European supervisors who came together on 4 November 2014 have certainly proven the sceptics wrong.

    We have come a long way since that day. The last ten years have been transformative both for the Single Supervisory Mechanism (SSM) and the banks we supervise. We have evolved from a start-up to a mature, risk-based and effective supervisor. Banks under our supervision have also evolved significantly, building up remarkable resilience. Unlike in the crises that predated the banking union, banks have now become part of the solution to economic shocks rather than the source. That’s good news.

    There is, however, no room for complacency.

    While past achievements provide a solid foundation, they are by no means a guarantee of future success. The macro-financial environment is changing profoundly. Unlike ten years ago, when the main risks emanated from banks themselves, today prudential risks are largely driven by an increasingly volatile and uncertain external environment.

    In my remarks, I will therefore focus on how supervisors and banks must adapt to this challenging environment. I will also address suggestions being put forward by some to relax banking regulation and supervision – suggestions which in my view are misguided. Compromising the resilience that has been carefully built up over the past ten years would undermine the objective of having a financial system that can support a competitive and sustainable economy.

    The first decade of European supervision: from start-up to maturity

    But before focusing on current challenges, I hope you’ll allow me to take a brief walk down memory lane. Where did we start from? What were the expectations a decade ago? And how did we go about meeting them?

    As Europe was looking into the abyss of the euro area sovereign debt crisis in 2012, legislators agreed on nothing less than a paradigm shift – the banking union, which represented the most significant leap forward in European integration since the introduction of the euro.

    The banking union encompasses three pillars, each with a straightforward task: first, European banking supervision to ensure that banks across Europe are subject to the same rules and high-quality supervisory standards. Second, European resolution to make sure that if banks fail, they can get resolved in an orderly manner instead of relying on the public purse. And third, European deposit insurance, to make sure that when push comes to shove, all depositors enjoy the same protection, no matter where in the euro area they are based.

    As far as the supervisory pillar is concerned, the ECB and the national competent authorities that make up the SSM were given a clear mission: ensuring the safety and soundness of banks. This is not just an end in itself – it is necessary so that banks remain at the service of people and businesses by funding innovation, productivity and sustainable growth.

    The destination was clear. But we had no roadmap to show us how to get there. There was no blueprint on how to transform a fragmented system of supervision into an integrated one. So it was by no means a given that the SSM would be a success.

    In the start-up phase of the SSM we were essentially crossing the bridge we were still building: we spent the mornings recruiting the best risk experts from across Europe, the afternoons supervising significant banks, and the evenings setting up our processes.

    When we started, there were plenty of ways in which supervisors across Europe looked at risks and how best to mitigate them. They all focused on different things: while some put the emphasis on credit file reviews, others focused on scrutinising banks’ internal risk management through the lens of the internal capital adequacy assessment process. Some supervisors chose to shine the spotlight more closely on governance or on-site culture.

    Thanks to the unwavering commitment and tireless energy of supervisors from the national competent authorities and the ECB, we consolidated the best practices from this wealth of supervisory experience into a common supervisory approach. What followed was a race to the top rather than to the bottom, resulting in high-quality supervision and a level playing field.

    On our path to becoming a mature organisation, we have adapted our processes along the way. Our supervision has evolved from being predominantly rule-based and heavily codified, to having a more flexible, agile and risk-focused approach.

    And banks under our supervision have also evolved significantly over the past ten years. Today, European banks are in much better shape than a decade ago.

    For instance, the financial resilience of SSM banks has notably improved. The aggregate Common Equity Tier 1 (CET1) ratio has increased from 12.7% in 2015 to 15.8% today, the liquidity coverage ratio has increased from 138% in 2016 to 159% today and the non-performing loan ratio of significant banks has declined from 7.5% in 2015 to 1.9% today.[1]

    Moreover, risk management, the effectiveness of internal control functions and governance arrangements in SSM banks have all improved.

    Over the past ten years, banks under European supervision have shown remarkable resilience even under the most challenging circumstances. They have evolved from shock propagators to shock absorbers, stabilising rather than de-stabilising the economy as it experienced significant shocks such as the pandemic, Russia’s unjustified war against Ukraine and the rapid changes to the interest rate environment. This resilience is also a testament to the crucial role played by European supervision, confirming that the SSM has lived up to the expectations that were placed on it a decade ago.[2]

    Highly complex, volatile and challenging risk landscape

    But there is no room for complacency. We can’t assume that the achievements of the past ten years will automatically pave the way for another successful decade of resilient banks under European supervision.

    We can’t ignore the fact that the world around us is changing. The macro-financial environment is characterised by unprecedented shocks, giving rise to new risk drivers. In the words of President Lagarde, in the last three years alone we have “faced the worst pandemic since the 1920s, the worst conflict in Europe since the 1940s and the worst energy shock since the 1970s”.[3]

    And as former US Treasury secretary Larry Summers put it, “this is the most complex, disparate and cross-cutting set of challenges that I can remember in the 40 years that I have been paying attention to such things’’.[4]

    In fact, the current combination of risks, challenges and uncertainties is staggering.

    A widening geopolitical divide and a global economy that is fragmenting into competing, increasingly protectionist blocs, give rise to new geopolitical risks.

    Heightened operational headwinds such as ever-more sophisticated cyberattacks and technology disruptions are challenging banks’ operational resilience.

    And last, but, alas, not least, we see the climate and nature crises unfolding, as evidenced by the horrific events last week in Paiporta and other villages and towns in the Spanish region of Valencia. On top of the human tragedy and physical destruction, the climate and nature crises are increasingly leading to material risks for banks.

    What makes this period so unprecedented is that these challenges are not happening one after the other – they are all happening at the same time. And there is no clear sign of them going away any time soon, rather the contrary.

    So how can supervisors and banks adjust to this era of polycrises?

    Ensuring bank resilience in the era of polycrises

    First and foremost, banks’ management bodies are the ones holding the steering wheel and must ensure that banks remain resilient and prepared for this new risk landscape. This involves making sure that banks have sound risk management that is commensurate to new risk drivers, that they maintain sufficient capital headroom to cushion against credible adverse scenarios, and that banks’ management bodies are effective in their steering and oversight function.

    While acknowledging that banks’ management bodies are in the driving seat, as supervisors we keep a close eye to ensure that no material risks are left unaddressed.[5] This means that we must be able to identify the risks and then ensure that banks are resilient to these risks.

    To ensure that our risk identification can keep up with the changing risk landscape, we have made our supervisory processes more agile. We simply cannot look at every risk with the same intensity, every year, in every bank we supervise. We have therefore started to implement a supervisory risk tolerance framework aiming at freeing up the desks and minds of supervisors. This allows our supervisors to focus on those risks that are most pertinent and the supervisory actions that are most impactful. In the same vein, we have also reformed our Supervisory Review and Evaluation Process (SREP) to make it more targeted and risk-based. Moreover, we are increasingly using supervisory technology tools – also known as suptech – to detect risks early on and move closer to real-time supervision.[6]

    These improvements to our processes give our supervisory teams more time to focus on the most relevant risks. By detecting vulnerabilities that would otherwise only surface later, we help banks to be better prepared and build up resilience proactively.

    Let me illustrate this with an example. Threats from cyberattacks are on the increase and are challenging banks’ operational resilience. In 2022, 50% of our supervised entities were subject to at least one successful attack – that number rose to 68% in just one year.[7] In order to help banks better identify their vulnerabilities to cyber risks and bolster their operational resilience, earlier this year we conducted a cyber resilience stress test[8] to gauge how well banks would be able to respond to and recover from a successful cyberattack while maintaining their critical functions and services. The cyber resilience stress test was an important learning exercise for banks; it helped them pinpoint areas where they need to build greater operational resilience to cyberattacks, which are unlikely to fade away in the current geopolitical risk environment.

    Let’s shift our focus from risk identification to remediation. As supervisors we must ensure that the risks we identify in our risk assessments are adequately managed. This also means that if we find deficiencies in the way banks are managing their risks, they must be remediated fully and in a timely manner, not at some unspecified point in the distant future. This is why we are putting more emphasis on impact and effectiveness.[9]

    To ensure full and timely remediation of our supervisory findings, we set out a time-bound remediation path. If a bank is not remedying the deficiency at a speed that will ensure full and timely remediation by the pre-established timeline, we will step up our supervisory action by deploying more intrusive measures from our ample supervisory toolkit. This is what we call the “escalation ladder”.

    The use of supervisory powers to compel banks to make concrete improvements is not just something we do within the SSM; it is international best practice.[10] The disorderly events of the March 2023 banking turmoil were a clear reminder of what can happen when banks leave material shortcomings unaddressed for too long.

    Banks and supervisors need to have the capacity to focus on emerging challenges. That’s why it is important to declutter our desks by tackling supervisory findings that have been with us for too long. While this is always an imperative, it is especially pertinent in the current challenging risk landscape.

    Let me illustrate this with the example of risk data aggregation and reporting. It is very hard to imagine any bank being able to appropriately manage its risks without strong risk data reporting. A bank’s ability to manage and aggregate risk-related data effectively is a pre-requisite for sound decision-making and robust risk governance. In fact, the Capital Requirements Directive, as transposed into national law, requires banks to put processes in place to identify all material risks. Worryingly, risk data aggregation and reporting was the lowest-scoring sub-category of internal governance in the 2023 SREP. In other words, despite the work done by supervisors over the years, too many banks still don’t have adequate risk data aggregation and reporting capabilities.

    It should not be a surprise that ECB Banking Supervision is stepping up the escalation ladder, using more intrusive supervisory tools to ensure that banks have adequate risk data aggregation capabilities. It’s not about forcing banks to do something that is merely an added perk; it’s about making sure they are able to manage material risks adequately and in good time. In a rapidly changing risk environment where prompt availability of reliable data has become essential, timely remediation of our supervisory findings on risk data aggregation is more important than ever.

    Deregulation and lenient supervision would compromise resilience

    After a decade of European supervision, it is not only the external risk environment that has changed. The current debate suggests that the perception by some of the role of financial regulation and supervision is also changing.

    Ten years ago, with the gloomy memories of the global financial crisis lingering in people’s minds, there was a strong consensus across society on the need for strong financial regulation and supervision in order to safeguard the public good of financial stability.

    Today, it appears that the pendulum is slowly swinging in the opposite direction. Some have raised the question as to whether regulation and supervision have become too conservative, to the point that they may constrain growth.

    Let me be clear: the argument being put forward in favour of relaxing banking regulation and supervision in order to promote growth is misguided.[11]

    We can’t allow the memory of the global financial crisis to fade. Its lessons are as relevant today as they were back in 2012, when the banking union was created. As deputy governor of the Bank of England, Sam Woods, correctly said, the great financial crisis was “the biggest growth-destroying event in recent economic history”.[Second, we would welcome if Member States were to resume discussions on setting-up a European-level public backstop to provide temporary liquidity funding to banks following resolution. The credibility of the resolution framework in Europe would be significantly enhanced by setting up a framework for liquidity in resolution.

    Moreover, building on the strong foundations of the SSM and the Single Resolution Mechanism, we must pave the way for a common European deposit insurance scheme (EDIS). In the first decade of the SSM, risks have been significantly reduced and common supervisory standards have been established. These preconditions for EDIS have now been met, and moving it forward will be important for severing any remaining feedback loops between banks and sovereigns, given that these proved so harmful during the sovereign debt crisis.

    Conclusion

    Let me conclude.

    Ten years ago today, when European supervisory teams started to come together for the first time, it was not at all certain that the SSM would be a success.

    We have since built a strong and effective supervisory framework in Europe, perceptive to evolving risks and – whenever necessary and appropriate – insistent in making sure that material risks are addressed. European banks have notably improved, proving resilient to shocks that we couldn’t have imagined a decade ago. This resilience is also a result of the strengthened supervisory and regulatory framework put in place after the global financial crisis, including the creation of the banking union.

    Ten years ago, the first Vice-Chair of the SSM, Sabine Lautenschläger, invoked the parallel of an athlete at the beginning of a career, who trained extremely hard and achieved an excellent result in a first major tournament.[15] To turn this promising start into a track record of sustained high performance, the athlete clearly cannot afford to rest on her laurels. Instead, she needs to go right back to the routine of constant training, to keep developing her skills and thus continue to build the foundation for future success on a day-to-day basis.

    This conclusion is as relevant today as it was ten year ago, especially considering the challenges along the path ahead.

    Considering the macro-financial environment and volatile risk landscape, it is safe to say that there is a high likelihood of unprecedented shocks continuing to emerge over the next decade. To make sure banks continue to serve European households and businesses under these challenging circumstances, we must ensure they remain resilient. Because a stable banking system forms the bedrock of long-term competitiveness and sustainable growth.

    European supervisors will continue to work tirelessly to make sure banks are well capitalised and adequately manage their risks. In this way, in ten years’ time we can celebrate another successful decade of resilient banks under European supervision.

    MIL OSI Economics

  • MIL-OSI Economics: WTO members review latest notifications of anti-dumping actions

    Source: WTO

    Headline: WTO members review latest notifications of anti-dumping actions

    The Committee reviewed new notifications of legislation submitted by Brazil, Cabo Verde, Solomon Islands and the United States. It continued its review of the legislative notifications of the European Union, Ghana, Liberia, and Saint Kitts and Nevis.
    In reviewing semi-annual notifications on anti-dumping actions, delegations questioned and discussed the practices of other members including in relation to the initiation of investigations, the imposition of provisional and final anti-dumping measures, and the review of existing anti-dumping measures. Delegations questioned and discussed actions contained in the semi-annual reports submitted by Brazil, China, the European Union, India, Indonesia, Malaysia, Pakistan, South Africa, Türkiye, the United Kingdom and the United States. In presenting its semi-annual report, Ukraine expressed concerns over the war in Ukraine and the effects on its domestic industry.
    In respect of the semi-annual reports covering the period 1 January – 30 June 2024, 45 members notified the Committee of anti-dumping actions taken in this period, while 15 reported no new anti-dumping actions in the same period. In addition, 51 members submitted one-time notifications indicating they have not established an authority competent to initiate and conduct an investigation and have not, to date, taken any anti-dumping actions.
    In addition to the semi-annual reports, the WTO’s Anti-Dumping Agreement requires members to submit without delay – on an ad hoc basis – notifications of all preliminary and final anti-dumping actions taken. Ad hoc notifications reviewed during the meeting were received from Argentina; Armenia; Australia; Brazil; Canada; Chile; China; the European Union; Georgia; India; Israel; Japan; Kazakhstan; the Republic of Korea; the Kyrgyz Republic; Mexico; Morocco; Pakistan; the Russian Federation; South Africa; Chinese Taipei; Türkiye; Ukraine; the United Kingdom; and the United States. Members raised questions and discussed actions taken by Australia, China and Morocco. Canada encouraged members to submit timely ad hoc notifications and raised concerns about the conduct of investigations it considered to be politically motivated which are not based on sufficient evidence or justification. 
    In the absence of the Chair of the Committee Mr Mohamed Zuhair Taous (Tunisia), the interim Chair Mr Wolfram Spelten (Germany), who was elected to preside over the October 2024 meetings of the Committee and of its subsidiary bodies, urged members that had not submitted semi-annual reports and ad hoc notifications of actions taken to do so promptly. The interim Chair welcomed members’ continued extensive use of the anti-dumping portal to submit their semi-annual reports. 
    The Committee adopted its 2024 annual report to the Council for Trade in Goods.
    Next meetings
    The Committee decided that its spring and autumn meetings for 2025 would be held in the weeks of 28 April and 27 October 2025, respectively.

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    MIL OSI Economics

  • MIL-OSI: Media Advisory: Fortinet Returns to World Economic Forum Annual Meeting on Cybersecurity

    Source: GlobeNewswire (MIL-OSI)

    SUNNYVALE, Calif., Nov. 04, 2024 (GLOBE NEWSWIRE) —

    Derek Manky, Chief Security Strategist and VP of Global Threat Intelligence at Fortinet
    “In today’s interconnected world, the fight against cybercrime requires a unified front. Public-private partnerships are vital for sharing threat intelligence, resources, and innovations that collectively help organizations worldwide stay ahead of digital adversaries. The World Economic Forum’s Annual Meeting on Cybersecurity continues to offer a unique opportunity for collaboration where fellow cybersecurity leaders share effective strategies and develop real-world solutions for disrupting cybercrime.”

    News Summary
    Fortinet® (NASDAQ: FTNT), the global cybersecurity leader driving the convergence of networking and security, today announced that the company will return to the World Economic Forum’s Annual Meeting on Cybersecurity in Geneva, Switzerland, from November 11 to 13. Fortinet is a founding member of the Forum’s Centre for Cybersecurity and will again engage in the yearly event, which brings together global cybersecurity leaders from business, government, international organizations, civil society, and academia to foster collaboration and enhance collective cyber resilience.

    Derek Manky, Fortinet Chief Security Strategist and VP of Global Threat Intelligence, will share expertise and insights as the moderator of a panel discussion on November 13 about countering cybercrime through public-private partnerships. In addition to his active role in the Forum and its Centre for Cybersecurity’s Partnership Against Cybercrime and the Cybercrime Atlas initiative, Derek is actively involved with global threat intelligence initiatives, including NATO NICPINTERPOL Expert Working Group, the Cyber Threat Alliance working committee, and FIRST, all in effort to shape the future of actionable threat intelligence and proactive security strategy.

    In the past year, as a leading contributor to the Cybercrime Atlas initiative, Fortinet has collaborated to promote new approaches to accelerate the fight against cybercrime. Significant progress has been made, with the Cybercrime Atlas community vetting more than 10,000 actionable data points, creating seven intelligence packages to support cyber defenders, and supporting two cross-border disruption campaigns through the group’s research and intelligence.

    Session Details

    Title: Better, Faster, Stronger: Accelerating Operational Collaborations to Disrupt Cybercrime
    When: November 13, 2024, 10:30 a.m. CET
    Where: World Economic Forum headquarters, Geneva, Switzerland
    Overview: Operational collaborations to counter cybercrime are leading to arrests and shutdowns of massive criminal networks in 2024. However, we are not yet collaborating at a scale or speed that will change the calculation for criminals. This session will offer insights into how to harness the lessons from successful operational collaborations around the world to systematically disrupt cybercriminals in 2025.
    Speakers:

    • Derek Manky, Chief Security Strategist and VP of Global Threat Intelligence, Fortinet (facilitator)
    • Edvardas Šileris, Head, European Cybercrime Centre (EC3), Europol
    • Brigadier General Oleksandr Potii, Deputy Chairman, State Service of Special Communications and Information Protection of Ukraine
    • Craig Rice, Chief Executive Officer, Cyber Defence Alliance
    • Samantha Kight, Head, Industry Security, Global System for Mobile Communications Association (GSMA)

    More about the World Economic Forum Annual Meeting on Cybersecurity

    In a rapidly evolving cyberspace, where innovation and technology continuously redefine boundaries, systemic inequity is emerging when it comes to the capabilities of
    organizations and countries to safeguard the benefits of technological progress.

    According to the World Economic Forum’s Global Cybersecurity Outlook 2024, the number of organizations maintaining minimum viable cyber resilience has decreased by 30%. This decline has further widened the skills gap in organizational cyber capabilities. The risks associated with this growing technological divide threaten the entire ecosystem and disproportionately impact the already vulnerable.

    Against this backdrop, the Annual Meeting on Cybersecurity 2024 will bring together over 150 of the world’s foremost cybersecurity leaders from business, government, international organizations, civil society, and academia to foster collaboration on making cyberspace safer and more resilient for all.

    Additional Resources

    About Fortinet
    Fortinet (NASDAQ: FTNT) is a driving force in the evolution of cybersecurity and the convergence of networking and security. Our mission is to secure people, devices, and data everywhere, and today we deliver cybersecurity everywhere you need it with the largest integrated portfolio of over 50 enterprise-grade products. Well over half a million customers trust Fortinet’s solutions, which are among the most deployed, most patented, and most validated in the industry. The Fortinet Training Institute, one of the largest and broadest training programs in the industry, is dedicated to making cybersecurity training and new career opportunities available to everyone. Collaboration with esteemed organizations from both the public and private sectors, including CERTs, government entities, and academia, is a fundamental aspect of Fortinet’s commitment to enhance cyber resilience globally. FortiGuard Labs, Fortinet’s elite threat intelligence and research organization, develops and utilizes leading-edge machine learning and AI technologies to provide customers with timely and consistently top-rated protection and actionable threat intelligence. Learn more at https://www.fortinet.com, the Fortinet Blog, and FortiGuard Labs. 

    Copyright © 2024 Fortinet, Inc. All rights reserved. The symbols ® and ™ denote respectively federally registered trademarks and common law trademarks of Fortinet, Inc., its subsidiaries and affiliates. Fortinet’s trademarks include, but are not limited to, the following: Fortinet, the Fortinet logo, FortiGate, FortiOS, FortiGuard, FortiCare, FortiAnalyzer, FortiManager, FortiASIC, FortiClient, FortiCloud, FortiMail, FortiSandbox, FortiADC, FortiAI, FortiAIOps, FortiAntenna, FortiAP, FortiAPCam, FortiAuthenticator, FortiCache, FortiCall, FortiCam, FortiCamera, FortiCarrier, FortiCASB, FortiCentral, FortiConnect, FortiController, FortiConverter, FortiCSPM, FortiCWP, FortDAST, FortiDB, FortiDDoS, FortiDeceptor, FortiDeploy, FortiDevSec, FortiEDR, FortiExplorer, FortiExtender, FortiFirewall, FortiFlex FortiFone, FortiGSLB, FortiGuest, FortiHypervisor, FortiInsight, FortiIsolator, FortiLAN, FortiLink, FortiMonitor, FortiNAC, FortiNDR, FortiPenTest, FortiPhish, FortiPoint, FortiPolicy, FortiPortal, FortiPresence, FortiProxy, FortiRecon, FortiRecorder, FortiSASE, FortiSDNConnector, FortiSEC, FortiSIEM, FortiSMS, FortiSOAR, FortiStack, FortiSwitch, FortiTester, FortiToken, FortiTrust, FortiVoice, FortiWAN, FortiWeb, FortiWiFi, FortiWLC, FortiWLM and FortiXDR. Other trademarks belong to their respective owners. Fortinet has not independently verified statements or certifications herein attributed to third parties and Fortinet does not independently endorse such statements. Notwithstanding anything to the contrary herein, nothing herein constitutes a warranty, guarantee, contract, binding specification or other binding commitment by Fortinet or any indication of intent related to a binding commitment, and performance and other specification information herein may be unique to certain environments.

    The MIL Network

  • MIL-OSI Global: How to Build a Truth Engine documentary makes for sober but crucial viewing in our age of disinformation

    Source: The Conversation – UK – By Clodagh Harrington, Lecturer in American Politics, University College Cork

    If the powerful documentary How to Build a Truth Engine had to be compressed into two thematic strands they might be “how the human mind works” and “how our brain can be manipulated by information”. Director Friedrich Moser’s film takes us on a two-hour voyage of explanation, covering issues from cyber-warfare to elections, COVID to conflict and more.

    Engaged citizens may find some of it they knew already. However, Moser offers a forensic and evidence-based delivery of how, why and the extent to which technology, events and the manipulation of both has had a powerful and deeply disconcerting impact on humans individually and collectively.

    As an expert in American politics, who recently wrote on the crisis of truth in the current US election, I found How to Build a Truth Engine makes for sober but crucial viewing.

    As our news cycles overflow with disinformation and fake news, this visually engaging film takes us on a calm, scientific tour of how we got to where we are – which is disinformation-central.

    Experts in neuroscience, engineering and even folklore explain the ways in which we think and process information. As humans, our brains rely on steady, clear streams of data. When these streams become polluted, our capacity to process and understand reality is challenged, and our vulnerability to false narratives increases.

    Clearly, lying for political purposes is as old as politics itself, but the capacity to disseminate these lies is now on a scale previously unimaginable, as the documentary shows.

    Unsurprisingly, Moser’s production gives much attention to the plight of traditional journalism. It also focuses on the challenges we face as consumers of news now that the process through which information is filtered and considered fit for dissemination has been dismantled to an alarming extent.

    The programme offers a stark reminder of the current state of conventional journalism, weakened by the migration of resources to online search engines where advertising and algorithms trump fact checking and truth telling.

    Among the topics covered is the 2022 Russian invasion of Bucha in Ukraine, in which multiple civilians were killed, with bound bodies left in the streets. At the time, the Kremlin rebuffed Ukrainian allegations of war crimes as a fake narrative and went so far as to state that the civilian massacre was a staged event.

    Western journalists, including New York Times staff, used satellite imagery to piece together events in the lead-up to the atrocity. As a result, they were able to verify what the Ukrainians had told them, but with the powerful addition of visual evidence, which transcended any “he said, she said” narrative.

    If truth is the first casualty of war, this important use of technology for such crucial purpose offers a ripple of accuracy in an ocean of falsehood.

    In highlighting the significance to the human brain of narrative and storytelling, the documentary offers chilling insights regarding the conspiracy theory path that led to the January 6 attack on the US Capitol in 2021. History is filled with tales of societies falling for false narratives, and the assault on the Capitol adheres to these criteria.

    From stereotyping to the creation of insider-outsider narratives (where certain groups are presented as relatable and others as negative and untrustworthy), it is only a small leap to negative assumptions about those deemed outsiders. In the case of January 6 Capitol attack in 2021, the documentary makes clear the groundwork was laid long before any violence took place.

    And so, we are reminded that the fiction that the 2020 election was stolen by Joe Biden was promoted, shared, amplified and repeated back (between Donald Trump, social media and sympathetic television networks) until the protesters were whipped into a frenzy. The result of this unchecked political propaganda was death and destruction.

    Those in Moser’s film offer a chilling reminder that as long as the lie of the “Big Steal”, as it is known now, remains alive as truth in the minds of many Americans, then it can happen again. If the relentless pursuit of accuracy is a core component of journalism, we can see that this pursuit is under constant siege as lies propagate at lightning speed and citizens choose their own truths.

    The documentary taps into the key question of our era: how do we know what we know? In an age of information warfare, truth is a valuable and vulnerable commodity. As humans, we have created technology so advanced that it is already outsmarting us.

    And truth is often diluted, polluted or drowned out completely in our daily communication torrents. This, combined with the nefarious agendas of bad actors means that individuals, communities and our way of life are under significant threat. The consolation, as presented by Moser’s work, may be that technology can also get us out of this predicament. That’s assuming that we want it to.



    Looking for something good? Cut through the noise with a carefully curated selection of the latest releases, live events and exhibitions, straight to your inbox every fortnight, on Fridays. Sign up here.


    Clodagh Harrington does not work for, consult, own shares in or receive funding from any company or organisation that would benefit from this article, and has disclosed no relevant affiliations beyond their academic appointment.

    ref. How to Build a Truth Engine documentary makes for sober but crucial viewing in our age of disinformation – https://theconversation.com/how-to-build-a-truth-engine-documentary-makes-for-sober-but-crucial-viewing-in-our-age-of-disinformation-242554

    MIL OSI – Global Reports

  • MIL-OSI: Viper Energy, Inc., a Subsidiary of Diamondback Energy, Inc., Reports Third Quarter 2024 Financial and Operating Results

    Source: GlobeNewswire (MIL-OSI)

    MIDLAND, Texas, Nov. 04, 2024 (GLOBE NEWSWIRE) — Viper Energy, Inc., (NASDAQ:VNOM) (“Viper” or the “Company”), a subsidiary of Diamondback Energy, Inc. (NASDAQ:FANG) (“Diamondback”), today announced financial and operating results for the third quarter ended September 30, 2024.

    THIRD QUARTER HIGHLIGHTS

    • Q3 2024 average production of 26,978 bo/d (49,370 boe/d), an increase of 2.4% from Q2 2024
    • Q3 2024 consolidated net income (including non-controlling interest) of $109.0 million; net income attributable to Viper Energy, Inc. of $48.9 million, or $0.52 per common share
    • Q3 2024 cash available for distribution to Viper’s common shares (as defined and reconciled below) of $75.4 million, or $0.73 per Class A common share
    • Declared Q3 2024 base cash dividend of $0.30 per Class A common share; implies a 2.3% annualized yield based on the November 1, 2024, share closing price of $52.16
    • Q3 2024 variable cash dividend of $0.31 per Class A common share; total base-plus-variable dividend of $0.61 per Class A common share implies a 4.7% annualized yield based on the November 1, 2024, share closing price of $52.16
    • Total Q3 2024 return of capital of $62.4 million, or $0.61 per Class A common share, represents 83% of cash available for distribution
    • 330 total gross (6.8 net 100% royalty interest) horizontal wells turned to production on Viper’s acreage during Q3 2024 with an average lateral length of 11,866 feet
    • As previously announced, closed acquisition of certain mineral and royalty interest-owning subsidiaries of Tumbleweed-Q Royalty Partners, LLC and MC Tumbleweed Royalty, LLC on September 3, 2024; closed acquisition of subsidiaries of Tumbleweed Royalty IV, LLC on October 1, 2024 (the “TWR IV acquisition” and collectively with the other Tumbleweed acquisitions, the “Tumbleweed Acquisitions”)
    • Initiating average daily production guidance for Q4 2024 of 29,250 to 29,750 bo/d (52,500 to 53,000 boe/d)
    • Increasing full year 2024 average daily production guidance to 27,000 to 27,250 bo/d (48,750 to 49,250 boe/d)

    “The third quarter marked a continuation of Viper delivering on its differentiated strategy and value proposition, and was highlighted by both continued organic production growth on our legacy asset base and the closing of the Tumbleweed Acquisitions. As we prepare to head into 2025, we look forward to further delivering on our strategy of consolidating high quality mineral and royalty assets through a disciplined and focused approach,” stated Travis Stice, Chief Executive Officer of Viper.

    Mr. Stice continued, “Looking specifically at current operations, activity remains strong across our acreage position as represented by the substantial amount of work-in-progress and line-of-sight wells, and we continue to benefit from Diamondback’s large scale development of our high concentration royalty acreage. We expect our durable production profile, along with our best-in-class cost structure, to continue to highlight the advantaged nature of our business model as we can maintain our strong free cash flow conversion despite the volatility in commodity prices.”

    FINANCIAL UPDATE

    Viper’s third quarter 2024 average unhedged realized prices were $75.24 per barrel of oil, $0.13 per Mcf of natural gas and $19.89 per barrel of natural gas liquids, resulting in a total equivalent realized price of $45.83/boe.

    Viper’s third quarter 2024 average hedged realized prices were $74.27 per barrel of oil, $0.56 per Mcf of natural gas and $19.89 per barrel of natural gas liquids, resulting in a total equivalent realized price of $45.87/boe.

    During the third quarter of 2024, the Company recorded total operating income of $209.6 million and consolidated net income (including non-controlling interest) of $109.0 million.

    As of September 30, 2024, the Company had a cash balance of $168.6 million and total long-term debt outstanding (excluding debt issuance costs, discounts and premiums) of $830.4 million, resulting in net debt (as defined and reconciled below) of $661.7 million. Viper’s outstanding long-term debt as of September 30, 2024 consisted of $430.4 million in aggregate principal amount of its 5.375% Senior Notes due 2027, $400.0 million in aggregate principal amount of its 7.375% Senior Notes due 2031 and no borrowings on its revolving credit facility, leaving $850.0 million available for future borrowings and $1.0 billion of total liquidity.

    Giving effect to the closing of the TWR IV acquisition on October 1, 2024 and the funding of the cash consideration of $458.9 million (of which $43.1 million had previously been paid into escrow, and the remainder was funded at closing with net proceeds from the underwritten public equity offering of Class A common stock that was completed on September 13, 2024, cash on hand, and borrowings under the revolving credit facility), pro forma net debt as of October 1, 2024 was approximately $1.1 billion.

    THIRD QUARTER 2024 CASH DIVIDEND & CAPITAL RETURN PROGRAM

    Viper announced today that the Board of Directors (the “Board”) of Viper Energy, Inc., declared a base dividend of $0.30 per Class A common share for the third quarter of 2024 payable on November 21, 2024 to Class A common shareholders of record at the close of business on November 14, 2024.

    The Board also declared a variable cash dividend of $0.31 per Class A common share for the third quarter of 2024 payable on November 21, 2024 to Class A common shareholders of record at the close of business on November 14, 2024.

    OPERATIONS UPDATE

    During the third quarter of 2024, Viper estimates that 330 gross (6.8 net 100% royalty interest) horizontal wells with an average royalty interest of 2.1% were turned to production on its acreage position with an average lateral length of 11,866 feet. Of these 330 gross wells, Diamondback is the operator of 81 gross wells, with an average royalty interest of 5.1%, and the remaining 249 gross wells, with an average royalty interest of 1.1%, are operated by third parties.

    Viper’s footprint of mineral and royalty interests was 32,567 net royalty acres as of September 30, 2024. Giving effect to the closing of the TWR IV acquisition on October 1, 2024, Viper’s pro forma acreage position was approximately 35,634 net royalty acres, of which Diamondback operated approximately 19,227 net royalty acres.

    Our gross well information as of October 1, 2024 is as follows, after giving effect to the Tumbleweed Acquisitions and Diamondback’s completed merger with Endeavor Energy Resources, L.P.:

      Diamondback
    Operated
      Third Party
    Operated
      Total
    Horizontal wells turned to production(1):          
    Gross wells         81     249     330  
    Net 100% royalty interest wells         4.1     2.7     6.8  
    Average percent net royalty interest         5.1 %   1.1 %   2.1 %
               
    Horizontal producing well count:          
    Gross wells         2,755     7,969     10,724  
    Net 100% royalty interest wells         150.1     102.0     252.1  
    Average percent net royalty interest         5.4 %   1.3 %   2.4 %
               
    Horizontal active development well count:          
    Gross wells         179     624     803  
    Net 100% royalty interest wells         10.4     7.3     17.7  
    Average percent net royalty interest         5.8 %   1.2 %   2.2 %
               
    Line of sight wells:          
    Gross wells         266     859     1,125  
    Net 100% royalty interest wells         8.6     13.4     22.0  
    Average percent net royalty interest         3.2 %   1.6 %   2.0 %

    (1) Average lateral length of 11,866 feet.

    The 803 gross wells currently in the process of active development are those wells that have been spud and are expected to be turned to production within approximately the next six to eight months. Further in regard to the active development on Viper’s asset base, there are currently 60 gross rigs operating on Viper’s acreage, seven of which are operated by Diamondback. The 1,125 line-of-sight wells are those that are not currently in the process of active development, but for which Viper has reason to believe that they will be turned to production within approximately the next 15 to 18 months. The expected timing of these line-of-sight wells is based primarily on permitting by third party operators or Diamondback’s current expected completion schedule. Existing permits or active development of Viper’s royalty acreage does not ensure that those wells will be turned to production.

    GUIDANCE UPDATE

    Below is Viper’s updated guidance for the full year 2024, as well as production guidance for Q4 2024.

       
      Viper Energy, Inc.
       
    Q4 2024 Net Production – MBo/d 29.25 – 29.75
    Q4 2024 Net Production – MBoe/d 52.50 – 53.00
    Full Year 2024 Net Production – MBo/d 27.00 – 27.25
    Full Year 2024 Net Production – MBoe/d 48.75 – 49.25
       
    Share costs ($/boe)  
    Depletion $11.50 – $12.00
    Cash G&A $0.80 – $1.00
    Non-Cash Share-Based Compensation $0.10 – $0.20
    Interest Expense $4.00 – $4.25
       
    Production and Ad Valorem Taxes (% of Revenue) ~7%
    Cash Tax Rate (% of Pre-Tax Income Attributable to Viper Energy, Inc.)(1) 20% – 22%
    Q4 2024 Cash Taxes ($ – million)(2) $13.0 – $18.0

    (1)   Pre-tax income attributable to Viper Energy, Inc. is reconciled below.
    (2)   Attributable to Viper Energy, Inc.

    CONFERENCE CALL

    Viper will host a conference call and webcast for investors and analysts to discuss its results for the third quarter of 2024 on Tuesday, November 5, 2024 at 10:00 a.m. CT. Access to the live audio-only webcast, and replay which will be available following the call, may be found here. The live webcast of the earnings conference call will also be available via Viper’s website at www.viperenergy.com under the “Investor Relations” section of the site.

    About Viper Energy, Inc.

    Viper is a corporation formed by Diamondback to own, acquire and exploit oil and natural gas properties in North America, with a focus on owning and acquiring mineral and royalty interests in oil-weighted basins, primarily the Permian Basin. For more information, please visit www.viperenergy.com.

    About Diamondback Energy, Inc.

    Diamondback is an independent oil and natural gas company headquartered in Midland, Texas focused on the acquisition, development, exploration and exploitation of unconventional, onshore oil and natural gas reserves primarily in the Permian Basin in West Texas. For more information, please visit www.diamondbackenergy.com.

    Forward-Looking Statements

    This news release contains “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act, which involve risks, uncertainties, and assumptions. All statements, other than statements of historical fact, including statements regarding Viper’s: future performance; business strategy; future operations; estimates and projections of operating income, losses, costs and expenses, returns, cash flow, and financial position; production levels on properties in which Viper has mineral and royalty interests, developmental activity by other operators; reserve estimates and Viper’s ability to replace or increase reserves; anticipated benefits or other effects of strategic transactions (including the recently completed TWR IV acquisition and other acquisitions or divestitures); and plans and objectives (including Diamondback’s plans for developing Viper’s acreage and Viper’s cash dividend policy and common stock repurchase program) are forward-looking statements. When used in this news release, the words “aim,” “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,” “intend,” “may,” “model,” “outlook,” “plan,” “positioned,” “potential,” “predict,” “project,” “seek,” “should,” “target,” “will,” “would,” and similar expressions (including the negative of such terms) as they relate to Viper are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Although Viper believes that the expectations and assumptions reflected in its forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond its control. Accordingly, forward-looking statements are not guarantees of Viper’s future performance and the actual outcomes could differ materially from what Viper expressed in its forward-looking statements.

    Factors that could cause the outcomes to differ materially include (but are not limited to) the following: changes in supply and demand levels for oil, natural gas, and natural gas liquids, and the resulting impact on the price for those commodities; the impact of public health crises, including epidemic or pandemic diseases, and any related company or government policies or actions; actions taken by the members of OPEC and Russia affecting the production and pricing of oil, as well as other domestic and global political, economic, or diplomatic developments, including any impact of the ongoing war in Ukraine and the Israel-Hamas war on the global energy markets and geopolitical stability; instability in the financial sector; higher interest rates and their impact on the cost of capital; regional supply and demand factors, including delays, curtailment delays or interruptions of production on Viper’s mineral and royalty acreage, or governmental orders, rules or regulations that impose production limits on such acreage; federal and state legislative and regulatory initiatives relating to hydraulic fracturing, including the effect of existing and future laws and governmental regulations; physical and transition risks relating to climate change and the risks and other factors disclosed in Viper’s filings with the Securities and Exchange Commission, including its Forms 10-K, 10-Q and 8-K, which can be obtained free of charge on the Securities and Exchange Commission’s web site at http://www.sec.gov.

    In light of these factors, the events anticipated by Viper’s forward-looking statements may not occur at the time anticipated or at all. Moreover, the new risks emerge from time to time. Viper cannot predict all risks, nor can it assess the impact of all factors on its business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those anticipated by any forward-looking statements it may make. Accordingly, you should not place undue reliance on any forward-looking statements made in this news release. All forward-looking statements speak only as of the date of this news release or, if earlier, as of the date they were made. Viper does not intend to, and disclaims any obligation to, update or revise any forward-looking statements unless required by applicable law.

    Viper Energy, Inc.
    Condensed Consolidated Balance Sheets
    (unaudited, in thousands, except share amounts)
           
      September 30,   December 31,
       2024     2023 
    Assets      
    Current assets:      
    Cash and cash equivalents         $ 168,649     $ 25,869  
    Royalty income receivable (net of allowance for credit losses)           108,857       108,681  
    Royalty income receivable—related party           35,997       3,329  
    Income tax receivable                 813  
    Derivative instruments           2,795       358  
    Prepaid expenses and other current assets           3,882       4,467  
    Total current assets           320,180       143,517  
    Property:      
    Oil and natural gas interests, full cost method of accounting ($1,622,601 and $1,769,341 excluded from depletion at September 30, 2024 and December 31, 2023, respectively)           4,771,268       4,628,983  
    Land           5,688       5,688  
    Accumulated depletion and impairment           (1,016,173 )     (866,352 )
    Property, net           3,760,783       3,768,319  
    Funds held in escrow           43,050        
    Derivative instruments           2,727       92  
    Deferred income taxes (net of allowances)           74,617       56,656  
    Other assets           4,653       5,509  
    Total assets         $ 4,206,010     $ 3,974,093  
    Liabilities and Stockholders’ Equity      
    Current liabilities:      
    Accounts payable         $ 26     $ 19  
    Accounts payable—related party                 1,330  
    Accrued liabilities           41,465       27,021  
    Derivative instruments           901       2,961  
    Income taxes payable           1,816       1,925  
    Total current liabilities           44,208       33,256  
    Long-term debt, net           821,505       1,083,082  
    Derivative instruments                 201  
    Other long-term liabilities           4,789        
    Total liabilities           870,502       1,116,539  
    Stockholders’ equity:      
    Class A Common Stock, $0.000001 par value: 1,000,000,000 shares authorized; 102,947,008 shares issued and outstanding as of September 30, 2024 and 86,144,273 shares issued and outstanding as of December 31, 2023                  
    Class B Common Stock, $0.000001 par value: 1,000,000,000 shares authorized; 85,431,453 shares issued and outstanding as of September 30, 2024 and 90,709,946 shares issued and outstanding as of December 31, 2023                  
    Additional paid-in capital           1,429,649       1,031,078  
    Retained earnings (accumulated deficit)           (28,691 )     (16,786 )
    Total Viper Energy, Inc. stockholders’ equity           1,400,958       1,014,292  
    Non-controlling interest           1,934,550       1,843,262  
    Total equity           3,335,508       2,857,554  
    Total liabilities and stockholders’ equity         $ 4,206,010     $ 3,974,093  
     
    Viper Energy, Inc.
    Condensed Consolidated Statements of Operations
    (unaudited, in thousands, except per share data)
                   
      Three Months Ended September 30,   Nine Months Ended September 30,
       2024     2023     2024     2023 
    Operating income:              
    Oil income         $ 186,750     $ 168,008     $ 558,203     $ 443,927  
    Natural gas income           823       8,893       8,763       22,974  
    Natural gas liquids income           20,585       18,713       61,745       47,995  
    Royalty income           208,158       195,614       628,711       514,896  
    Lease bonus income—related party           107       97,237       227       105,585  
    Lease bonus income           1,143       196       2,289       1,730  
    Other operating income           180       193       461       774  
    Total operating income           209,588       293,240       631,688       622,985  
    Costs and expenses:              
    Production and ad valorem taxes           15,113       12,286       44,720       37,794  
    Depletion           54,528       36,280       149,821       101,331  
    General and administrative expenses—related party           2,569       924       7,391       2,772  
    General and administrative expenses           2,046       956       6,712       3,880  
    Other operating (income) expense           (236 )           (3 )      
    Total costs and expenses           74,020       50,446       208,641       145,777  
    Income (loss) from operations           135,568       242,794       423,047       477,208  
    Other income (expense):              
    Interest expense, net           (16,739 )     (10,970 )     (54,736 )     (31,636 )
    Gain (loss) on derivative instruments, net           7,410       (2,988 )     5,264       (30,685 )
    Other income, net                 256             258  
    Total other expense, net           (9,329 )     (13,702 )     (49,472 )     (62,063 )
    Income (loss) before income taxes           126,239       229,092       373,575       415,145  
    Provision for (benefit from) income taxes           17,194       21,879       42,729       39,735  
    Net income (loss)           109,045       207,213       330,846       375,410  
    Net income (loss) attributable to non-controlling interest           60,128       128,614       181,668       232,294  
    Net income (loss) attributable to Viper Energy, Inc.         $ 48,917     $ 78,599     $ 149,178     $ 143,116  
                   
    Net income (loss) attributable to common shares:              
    Basic         $ 0.52     $ 1.11     $ 1.64     $ 1.99  
    Diluted         $ 0.52     $ 1.11     $ 1.64     $ 1.99  
    Weighted average number of common shares outstanding:              
    Basic           93,695       70,925       90,895       71,803  
    Diluted           93,747       70,925       90,989       71,803  
                                   
    Viper Energy, Inc.
    Condensed Consolidated Statements of Cash Flows
    (unaudited, in thousands)
                   
      Three Months Ended September 30,   Nine Months Ended September 30,
      2024   2023   2024   2023
    Cash flows from operating activities:              
    Net income (loss)         $ 109,045     $ 207,213     $ 330,846     $ 375,410  
    Adjustments to reconcile net income (loss) to net cash provided by operating activities:                      
    Provision for (benefit from) deferred income taxes           1,777       355       (505 )     887  
    Depletion           54,528       36,280       149,821       101,331  
    (Gain) loss on derivative instruments, net           (7,410 )     2,988       (5,264 )     30,685  
    Net cash receipts (payments) on derivatives           187       (3,807 )     (2,038 )     (10,019 )
    Other           1,390       823       4,470       2,045  
    Changes in operating assets and liabilities:              
    Royalty income receivable           26,163       (23,039 )     2,886       (22,147 )
    Royalty income receivable—related party           (1,015 )     (3,047 )     (32,667 )     (1,171 )
    Accounts payable and accrued liabilities           19,107       6,739       14,192       4,156  
    Accounts payable—related party                       (1,330 )     (306 )
    Income taxes payable           (385 )     11,738       (109 )     12,411  
    Other           (413 )     3,485       1,398       (885 )
    Net cash provided by (used in) operating activities           202,974       239,728       461,700       492,397  
    Cash flows from investing activities:              
    Acquisitions of oil and natural gas interests—related party                             (75,073 )
    Acquisitions of oil and natural gas interests           (241,877 )     (51,101 )     (271,052 )     (98,510 )
    Proceeds from sale of oil and natural gas interests           (2,967 )     (1,191 )     87,674       (3,166 )
    Net cash provided by (used in) investing activities           (244,844 )     (52,292 )     (183,378 )     (176,749 )
    Cash flows from financing activities:              
    Proceeds from borrowings under credit facility           375,000       69,000       470,000       260,000  
    Repayment on credit facility           (552,000 )     (43,000 )     (733,000 )     (162,000 )
    Net proceeds from public offering           475,904             475,904        
    Repurchased shares/units under buyback program                 (9,650 )           (67,181 )
    Dividends/distributions to stockholders           (58,649 )     (25,300 )     (156,553 )     (84,181 )
    Dividends/distributions to Diamondback            (64,947 )     (40,200 )     (191,830 )     (127,929 )
    Other                 (4,551 )     (63 )     (5,722 )
    Net cash provided by (used in) financing activities           175,308       (53,701 )     (135,542 )     (187,013 )
    Net increase (decrease) in cash and cash equivalents           133,438       133,735       142,780       128,635  
    Cash, cash equivalents and restricted cash at beginning of period           35,211       13,079       25,869       18,179  
    Cash, cash equivalents and restricted cash at end of period         $ 168,649     $ 146,814     $ 168,649     $ 146,814  
     
    Viper Energy, Inc.
    Selected Operating Data
    (unaudited)
               
      Three Months Ended
      September 30, 2024   June 30, 2024   September 30, 2023
    Production Data:          
    Oil (MBbls)           2,482     2,398     2,037
    Natural gas (MMcf)           6,150     5,631     4,900
    Natural gas liquids (MBbls)           1,035     983     867
    Combined volumes (MBoe)(1)           4,542     4,320     3,721
               
    Average daily oil volumes (bo/d)           26,978     26,352     22,141
    Average daily combined volumes (boe/d)           49,370     47,473     40,446
               
    Average sales prices:          
    Oil ($/Bbl)         $ 75.24   $ 81.04   $ 82.48
    Natural gas ($/Mcf)         $ 0.13   $ 0.20   $ 1.81
    Natural gas liquids ($/Bbl)         $ 19.89   $ 20.35   $ 21.58
    Combined ($/boe)(2)         $ 45.83   $ 49.88   $ 52.57
               
    Oil, hedged ($/Bbl)(3)         $ 74.27   $ 80.24   $ 81.44
    Natural gas, hedged ($/Mcf)(3)         $ 0.56   $ 0.64   $ 1.47
    Natural gas liquids ($/Bbl)(3)         $ 19.89   $ 20.35   $ 21.58
    Combined price, hedged ($/boe)(3)         $ 45.87   $ 50.00   $ 51.55
               
    Average Costs ($/boe):          
    Production and ad valorem taxes         $ 3.33   $ 3.52   $ 3.30
    General and administrative – cash component           0.83     0.84     0.41
    Total operating expense – cash         $ 4.16   $ 4.36   $ 3.71
               
    General and administrative – non-cash stock compensation expense         $ 0.19   $ 0.19   $ 0.10
    Interest expense, net         $ 3.69   $ 4.32   $ 2.95
    Depletion         $ 12.01   $ 11.19   $ 9.75

    (1)   Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.
    (2)   Realized price net of all deducts for gathering, transportation and processing.
    (3)   Hedged prices reflect the impact of cash settlements of our matured commodity derivative transactions on our average sales prices.

    NON-GAAP FINANCIAL MEASURES

    Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. Viper defines Adjusted EBITDA as net income (loss) attributable to Viper Energy, Inc. plus net income (loss) attributable to non-controlling interest (“net income (loss)”) before interest expense, net, non-cash share-based compensation expense, depletion, non-cash (gain) loss on derivative instruments, (gain) loss on extinguishment of debt, if any, other non-cash operating expenses, other non-recurring expenses and provision for (benefit from) income taxes. Adjusted EBITDA is not a measure of net income as determined by United States’ generally accepted accounting principles (“GAAP”). Management believes Adjusted EBITDA is useful because it allows them to more effectively evaluate Viper’s operating performance and compare the results of its operations from period to period without regard to its financing methods or capital structure. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income, royalty income, cash flow from operating activities or any other measure of financial performance or liquidity presented as determined in accordance with GAAP. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDA.

    Viper defines cash available for distribution to Viper Energy, Inc. shareholders generally as an amount equal to its Adjusted EBITDA for the applicable quarter less cash needed for income taxes payable for the current period, debt service, contractual obligations, fixed charges and reserves for future operating or capital needs that the Board may deem appropriate, lease bonus income, net of tax, distribution equivalent rights payments, preferred dividends, and an adjustment for changes in ownership interests that occurred subsequent to the quarter, if any. Management believes cash available for distribution is useful because it allows them to more effectively evaluate Viper’s operating performance excluding the impact of non-cash financial items and short-term changes in working capital. Viper’s computations of Adjusted EBITDA and cash available for distribution may not be comparable to other similarly titled measures of other companies or to such measure in its credit facility or any of its other contracts. Viper further defines cash available for variable dividends as at least 75 percent of cash available for distribution less base dividends declared and repurchased shares as part of its share buyback program for the applicable quarter.

    The following tables present a reconciliation of the GAAP financial measure of net income (loss) to the non-GAAP financial measures of Adjusted EBITDA, cash available for distribution and cash available for variable dividends:

    Viper Energy, Inc.
    (unaudited, in thousands, except per share data)
       
      Three Months Ended
    September 30, 2024
    Net income (loss) attributable to Viper Energy, Inc.         $ 48,917  
    Net income (loss) attributable to non-controlling interest           60,128  
    Net income (loss)           109,045  
    Interest expense, net           16,739  
    Non-cash share-based compensation expense           845  
    Depletion           54,528  
    Non-cash (gain) loss on derivative instruments           (7,223 )
    Other non-cash operating expenses           (236 )
    Other non-recurring expenses           92  
    Provision for (benefit from) income taxes           17,194  
    Consolidated Adjusted EBITDA           190,984  
    Less: Adjusted EBITDA attributable to non-controlling interest           86,613  
    Adjusted EBITDA attributable to Viper Energy, Inc.         $ 104,371  
       
    Adjustments to reconcile Adjusted EBITDA to cash available for distribution:  
    Income taxes payable for the current period         $ (15,416 )
    Debt service, contractual obligations, fixed charges and reserves           (8,922 )
    Lease bonus income, net of tax           (479 )
    Distribution equivalent rights payments           (123 )
    Preferred distributions                   (20 )
    Effect of subsequent ownership changes                   (3,963 )
    Cash available for distribution to Viper Energy, Inc. shareholders         $ 75,448  
      Three Months Ended September 30, 2024
      Amounts   Amounts Per
    Common Share
    Reconciliation to cash available for variable dividends:      
    Cash available for distribution to Viper Energy, Inc. shareholders         $ 75,448   $ 0.73
           
    Return of Capital          $ 62,375   $ 0.61
    Less:      
    Base dividend           30,884     0.30
    Cash available for variable dividends         $ 31,491   $ 0.31
           
    Total approved base and variable dividend per share             $ 0.61
           
    Class A common stock outstanding               102,947

    The following table presents a reconciliation of the GAAP financial measure of income (loss) before income taxes to the non-GAAP financial measure of pre-tax income attributable to Viper Energy, Inc. Management believes this measure is useful to investors given it provides the basis for income taxes payable by Viper Energy, Inc, which is an adjustment to reconcile Adjusted EBITDA to cash available for distribution to holders of Viper Energy, Inc. Class A common stock.

    Viper Energy, Inc.
    Pre-tax income attributable to Viper Energy, Inc.
    (unaudited, in thousands)
       
      Three Months Ended
    September 30, 2024
     
    Income (loss) before income taxes         $ 126,239  
    Less: Net income (loss) attributable to non-controlling interest           60,128  
    Pre-tax income attributable to Viper Energy, Inc.         $ 66,111  
       
    Income taxes payable for the current period         $ 15,416  
    Effective cash tax rate attributable to Viper Energy, Inc.           23.3 %

    Adjusted net income (loss) is a non-GAAP financial measure equal to net income (loss) attributable to Viper Energy, Inc. plus net income (loss) attributable to non-controlling interest adjusted for non-cash (gain) loss on derivative instruments, net, (gain) loss on extinguishment of debt, if any, other non-cash operating expenses, other non-recurring expenses and related income tax adjustments. The Company’s computation of adjusted net income may not be comparable to other similarly titled measures of other companies or to such measure in our credit facility or any of our other contracts. Management believes adjusted net income helps investors in the oil and natural gas industry to measure and compare the Company’s performance to other oil and natural gas companies by excluding from the calculation items that can vary significantly from company to company depending upon accounting methods, the book value of assets and other non-operational factors.

    The following table presents a reconciliation of the GAAP financial measure of net income (loss) attributable to Viper Energy, Inc. to the non-GAAP financial measure of adjusted net income (loss):

    Viper Energy, Inc.
    Adjusted Net Income (Loss)
    (unaudited, in thousands, except per share data)
       
      Three Months Ended September 30, 2024
      Amounts   Amounts Per
    Diluted Share
    Net income (loss) attributable to Viper Energy, Inc. (1)         $ 48,917     $ 0.52  
    Net income (loss) attributable to non-controlling interest           60,128       0.64  
    Net income (loss)(1)            109,045       1.16  
    Non-cash (gain) loss on derivative instruments, net           (7,223 )     (0.08 )
    Other non-cash operating expenses           (236 )      
    Other non-recurring expenses           92        
    Adjusted income excluding above items(1)            101,678       1.08  
    Income tax adjustment for above items           1,003       0.02  
    Adjusted net income (loss)(1)            102,681       1.10  
    Less: Adjusted net income (loss) attributed to non-controlling interests           57,059       0.61  
    Adjusted net income (loss) attributable to Viper Energy, Inc. (1)          $ 45,622     $ 0.49  
           
    Weighted average Class A common shares outstanding:      
    Basic           93,695  
    Diluted           93,747  

    (1) The Company’s earnings (loss) per diluted share amount has been computed using the two-class method in accordance with GAAP. The two-class method is an earnings allocation which reflects the respective ownership among holders of Class A common shares and participating securities. Diluted earnings per share using the two-class method is calculated as (i) net income attributable to Viper Energy, Inc., (ii) less the reallocation of $0.1 million in earnings attributable to participating securities, (iii) divided by diluted weighted average Class A common shares outstanding.

    RECONCILIATION OF LONG-TERM DEBT TO NET DEBT

    The Company defines the non-GAAP measure of net debt as debt (excluding debt issuance costs, discounts and premiums) less cash and cash equivalents. Net debt should not be considered an alternative to, or more meaningful than, total debt, the most directly comparable GAAP measure. Management uses net debt to determine the Company’s outstanding debt obligations that would not be readily satisfied by its cash and cash equivalents on hand. The Company believes this metric is useful to analysts and investors in determining the Company’s leverage position because the Company has the ability to, and may decide to, use a portion of its cash and cash equivalents to reduce debt.

        September 30, 2024   Net Q3
    Principal
    Borrowings/
    (Repayments)
      June 30, 2024   March 31, 2024   December 31, 2023   September 30, 2023
        (in thousands)
    Total long-term debt(1)   $ 830,350     $ (177,000 )   $ 1,007,350     $ 1,103,350     $ 1,093,350     $ 680,350  
    Cash and cash equivalents     (168,649 )         (35,211 )     (20,005 )     (25,869 )     (146,814 )
    Net debt   $ 661,701         $ 972,139     $ 1,083,345     $ 1,067,481     $ 533,536  

    (1) Excludes debt issuance costs, discounts & premiums.

    Derivatives

    As of the filing date, the Company had the following outstanding derivative contracts. The Company’s derivative contracts are based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on New York Mercantile Exchange West Texas Intermediate pricing and Crude Oil Brent. When aggregating multiple contracts, the weighted average contract price is disclosed.

      Crude Oil (Bbls/day, $/Bbl)
      Q4 2024   Q1 2025   Q2 2025   Q3 2025   Q4 2025
    Deferred Premium Puts – WTI (Cushing)   16,000       20,000       20,000          
    Strike $ 55.00     $ 55.00     $ 55.00     $   $
    Premium $ (1.70 )   $ (1.62 )   $ (1.61 )   $   $
      Crude Oil (Bbls/day, $/Bbl)
      Q4 2024   Q1 2025   Q2 2025   Q3 2025   Q4 2025
    Costless Collars – WTI (Cushing)   4,000                
    Floor $ 55.00   $   $   $   $
    Ceiling $ 93.66   $   $   $   $
      Natural Gas (Mmbtu/day, $/Mmbtu)
      Q4 2024   Q1 2025   Q2 2025   Q3 2025   Q4 2025
    Costless Collars – Henry Hub       60,000     60,000     60,000     60,000
    Floor $   $ 2.50   $ 2.50   $ 2.50   $ 2.50
    Ceiling $   $ 4.93   $ 4.93   $ 4.93   $ 4.93
      Natural Gas (Mmbtu/day, $/Mmbtu)
      Q4 2024   Q1 2025   Q2 2025   Q3 2025   Q4 2025
    Natural Gas Basis Swaps – Waha Hub   30,000       60,000       60,000       60,000       60,000  
    Swap Price $ (1.20 )   $ (0.80 )   $ (0.80 )   $ (0.80 )   $ (0.80 )

    Investor Contact:

    Austen Gilfillian
    +1 432.221.7420
    agilfillian@viperenergy.com 

    Source: Viper Energy, Inc.; Diamondback Energy, Inc.

    The MIL Network

  • MIL-OSI: Diamondback Energy, Inc. Announces Third Quarter 2024 Financial and Operating Results

    Source: GlobeNewswire (MIL-OSI)

    MIDLAND, Texas, Nov. 04, 2024 (GLOBE NEWSWIRE) — Diamondback Energy, Inc. (NASDAQ: FANG) (“Diamondback” or the “Company”) today announced financial and operating results for the third quarter ended September 30, 2024.

    THIRD QUARTER 2024 HIGHLIGHTS

    • As previously announced, closed merger with Endeavor Energy Resources, L.P. (“Endeavor”) on September 10, 2024
    • Average production of 321.1 MBO/d (571.1 MBOE/d)
    • Net cash provided by operating activities of $1.2 billion; Operating Cash Flow Before Working Capital Changes (as defined and reconciled below) of $1.4 billion
    • Cash capital expenditures of $688 million
    • Free Cash Flow (as defined and reconciled below) of $708 million; Adjusted Free Cash Flow (as defined and reconciled below) of $1.0 billion
    • Declared Q3 2024 base cash dividend of $0.90 per share payable on November 21, 2024; implies a 2.0% annualized yield based on November 1, 2024 closing share price of $175.81
    • Repurchased 2,919,763 shares of common stock in Q3 2024 for $515 million, excluding excise tax (at a weighted average price of $176.40 per share); repurchased 1,029,191 shares of common stock to date in Q4 2024 for $185 million, excluding excise tax (at a weighted average price of $180.13 per share)
    • Total Q3 2024 return of capital of $780 million; represents ~78% of Adjusted Free Cash Flow (as defined and reconciled below) from stock repurchases and the declared Q3 2024 base dividend
    • As previously announced, Board approved a $2.0 billion increase to share repurchase authorization to $6.0 billion from $4.0 billion previously

    TRP ENERGY (“TRP”) TRADE

    • On November 3rd, Diamondback and TRP entered into a definitive agreement under which Diamondback will trade certain Delaware Basin assets and pay approximately $238 million in cash to TRP in exchange for TRP’s Midland Basin assets
    • TRP’s Midland Basin assets are made up of ~15,000 net acres across Upton and Reagan counties and consist of 55 remaining undeveloped operated locations, the majority of which immediately compete for capital
    • The asset also includes 18 Drilled Uncompleted Wells (“DUCs”) which provide for additional capital allocation flexibility
    • The trade is expected to be accretive to both Cash Flow and Free Cash Flow per share and enhances Diamondback’s near-term oil production profile
    • Expected to close in December 2024, subject to customary regulatory approvals and closing conditions
    • Jefferies LLC is serving as financial advisor to Diamondback. Kirkland & Ellis LLP is serving as legal advisor to Diamondback. J.P. Morgan Securities LLC, Moelis & Company and RBC Capital Markets are acting as financial advisors to TRP. Clifford Chance US LLP is serving as legal advisor to TRP.

    OPERATIONS UPDATE

    The tables below provide a summary of operating activity for the third quarter of 2024.

      Total Activity (Gross Operated):        
        Number of Wells
    Drilled
      Number of Wells
    Completed
     
      Midland Basin 71   87  
      Delaware Basin 5   8  
      Total 76   95  
      Total Activity (Net Operated):        
        Number of Wells
    Drilled
    (1)
      Number of Wells
    Completed
    (1)
     
      Midland Basin 67   95  
      Delaware Basin 4   7  
      Total 71   102  
      (1) Includes two additional net wells drilled and nine additional net wells completed, respectively, from interests acquired in the Endeavor Acquisition during the first six months of 2024.  
               

    During the third quarter of 2024, Diamondback drilled 71 gross wells in the Midland Basin and five gross wells in the Delaware Basin. The Company turned 87 operated wells to production in the Midland Basin and eight gross wells in the Delaware Basin, with an average lateral length of 12,238 feet. Operated completions during the third quarter consisted of 22 Wolfcamp A wells, 21 Lower Spraberry wells, 15 Jo Mill wells, 14 Wolfcamp B wells, 12 Middle Spraberry wells, four Dean wells, four Third Bone Spring wells and three Upper Spraberry wells.

    For the first nine months of 2024, Diamondback drilled 211 gross wells in the Midland Basin and 24 gross wells in the Delaware Basin. The Company turned 267 operated wells to production in the Midland Basin and 15 operated wells to production in the Delaware Basin. The average lateral length for wells completed during the first nine months of 2024 was 11,645 feet, and consisted of 72 Lower Spraberry wells, 61 Wolfcamp A wells, 45 Wolfcamp B wells, 40 Jo Mill wells, 34 Middle Spraberry wells, nine Wolfcamp D wells, nine Dean wells, six Upper Spraberry wells, four Third Bone Spring wells, one Second Bone Spring well and one Barnett well.

    FINANCIAL UPDATE

    Diamondback’s third quarter 2024 net income was $659 million, or $3.19 per diluted share. Adjusted net income (as defined and reconciled below) for the third quarter was $698 million, or $3.38 per diluted share.

    Third quarter 2024 net cash provided by operating activities was $1.2 billion. Through the first nine months of 2024, Diamondback’s net cash provided by operating activities was $4.1 billion.

    During the third quarter of 2024, Diamondback spent $633 million on operated and non-operated drilling and completions, $52 million on infrastructure and environmental and $3 million on midstream, for total cash capital expenditures of $688 million. Through the first nine months of 2024, Diamondback spent $1.8 billion on operated and non-operated drilling and completions, $128 million on infrastructure and environmental and $8 million on midstream, for total cash capital expenditures of $1.9 billion.

    Third quarter 2024 Consolidated Adjusted EBITDA (as defined and reconciled below) was $1.8 billion. Adjusted EBITDA net of non-controlling interest (as defined and reconciled below) for the third quarter was $1.7 billion.

    Diamondback’s third quarter 2024 Free Cash Flow (as defined and reconciled below) was $708 million. Adjusted Free Cash Flow (as reconciled and defined below) for the third quarter was $1.0 billion. Through September 30, 2024, Diamondback’s Free Cash Flow was $2.3 billion, with $2.7 billion of Adjusted Free Cash Flow over the same period.

    Third quarter 2024 average unhedged realized prices were $73.13 per barrel of oil, $(0.26) per Mcf of natural gas and $17.70 per barrel of natural gas liquids (“NGLs”), resulting in a total equivalent unhedged realized price of $44.80 per BOE.

    Diamondback’s cash operating costs for the third quarter of 2024 were $11.49 per BOE, including lease operating expenses (“LOE”) of $6.01 per BOE, cash general and administrative (“G&A”) expenses of $0.63 per BOE, production and ad valorem taxes of $2.91 per BOE and gathering, processing and transportation expenses of $1.94 per BOE.

    As of September 30, 2024, Diamondback had $201 million in standalone cash and $115 million in borrowings outstanding under its revolving credit facility, with approximately $2.4 billion available for future borrowings under the facility and approximately $2.6 billion of total liquidity. As of September 30, 2024, the Company had consolidated total debt of $13.1 billion and consolidated net debt (as defined and reconciled below) of $12.7 billion, up from consolidated total debt of $12.2 billion and up from consolidated net debt of $5.3 billion as of June 30, 2024. Effective in September 2024, the Company’s borrowing base and elected commitment was increased to $2.5 billion from $1.6 billion previously.

    DIVIDEND DECLARATIONS

    Diamondback announced today that the Company’s Board of Directors declared a base cash dividend of $0.90 per common share for the third quarter of 2024 payable on November 21, 2024 to stockholders of record at the close of business on November 14, 2024.

    Future base and variable dividends remain subject to review and approval at the discretion of the Company’s Board of Directors.

    COMMON STOCK REPURCHASE PROGRAM

    During the third quarter of 2024, Diamondback repurchased ~2.9 million shares of common stock at an average share price of $176.40 for a total cost of approximately $515 million, excluding excise tax. To date, Diamondback has repurchased ~23.3 million shares of common stock at an average share price of $133.48 for a total cost of approximately $3.1 billion and has approximately $2.9 billion remaining on its current share buyback authorization. Subject to factors discussed below, Diamondback intends to continue to purchase common stock under the common stock repurchase program opportunistically with cash on hand, free cash flow from operations and proceeds from potential liquidity events such as the sale of assets. This repurchase program has no time limit and may be suspended from time to time, modified, extended or discontinued by the Board at any time. Purchases under the repurchase program may be made from time to time in privately negotiated transactions, or in open market transactions in compliance with Rule 10b-18 under the Securities Exchange Act of 1934, as amended, and will be subject to market conditions, applicable regulatory and legal requirements and other factors. Any common stock purchased as part of this program will be retired.

    UPDATED 2024 GUIDANCE

    Below is Diamondback’s guidance for the full year 2024, which includes fourth quarter production, unit costs and capital guidance. The Company’s production and capital guidance for the full year 2024 has been updated to give effect to the Endeavor merger, which was completed on September 10, 2024.

      2024 Guidance 2024 Guidance
      Diamondback Energy, Inc. Viper Energy, Inc.
         
    2024 Net production – MBOE/d 587 – 590 (from 462 – 470) 48.75 – 49.25
    2024 Oil production – MBO/d 335 – 337 (from 273 – 276) 27.00 – 27.25
    Q4 2024 Oil production – MBO/d (total – MBOE/d) 470 – 475 (840 – 850) 29.25 – 29.75 (52.50 – 53.00)
         
    Q4 2024 Unit costs ($/BOE)    
    Lease operating expenses, including workovers $5.90 – $6.20  
    G&A    
    Cash G&A $0.55 – $0.65  
    Non-cash equity-based compensation $0.25 – $0.40  
    DD&A $14.00 – $15.00  
    Interest expense (net of interest income) $0.25 – $0.50  
    Gathering, processing and transportation $1.60 – $1.80  
         
    Production and ad valorem taxes (% of revenue) ~7%  
    Corporate tax rate (% of pre-tax income) 23%  
    Cash tax rate (% of pre-tax income) 15% – 18%  
    Cash taxes ($ – million) $240 – $300 $13 – $18
         
    Capital Budget ($ – million)    
    2024 Total capital expenditures $2,875 – $3,000 (from $2,350 – $2,450)  
    Q4 2024 Capital expenditures $950 – $1,050  
         
    Q4 2024 Gross horizontal wells drilled (net) 105 – 125 (100 – 118)  
    Q4 2024 Gross horizontal wells completed (net) 110 – 130 (102 – 120)  
         

    CONFERENCE CALL

    Diamondback will host a conference call and webcast for investors and analysts to discuss its results for the third quarter of 2024 on Tuesday, November 5, 2024 at 8:00 a.m. CT. Access to the webcast, and replay which will be available following the call, may be found here. The live webcast of the earnings conference call will also be available via Diamondback’s website at www.diamondbackenergy.com under the “Investor Relations” section of the site.

    About Diamondback Energy, Inc.

    Diamondback is an independent oil and natural gas company headquartered in Midland, Texas focused on the acquisition, development, exploration and exploitation of unconventional, onshore oil and natural gas reserves primarily in the Permian Basin in West Texas. For more information, please visit www.diamondbackenergy.com.

    Forward-Looking Statements

    This news release contains “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act, which involve risks, uncertainties, and assumptions. All statements, other than statements of historical fact, including statements regarding Diamondback’s: future performance; business strategy; future operations (including drilling plans and capital plans); estimates and projections of revenues, losses, costs, expenses, returns, cash flow, and financial position; reserve estimates and its ability to replace or increase reserves; anticipated benefits or other effects of strategic transactions (including the recently completed Endeavor merger and other acquisitions or divestitures); and plans and objectives of management (including plans for future cash flow from operations and for executing environmental strategies) are forward-looking statements. When used in this news release, the words “aim,” “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,” “intend,” “may,” “model,” “outlook,” “plan,” “positioned,” “potential,” “predict,” “project,” “seek,” “should,” “target,” “will,” “would,” and similar expressions (including the negative of such terms) as they relate to Diamondback are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Although Diamondback believes that the expectations and assumptions reflected in its forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond Diamondback’s control. Accordingly, forward-looking statements are not guarantees of future performance and Diamondback’s actual outcomes could differ materially from what Diamondback has expressed in its forward-looking statements.

    Factors that could cause the outcomes to differ materially include (but are not limited to) the following: changes in supply and demand levels for oil, natural gas, and natural gas liquids, and the resulting impact on the price for those commodities; the impact of public health crises, including epidemic or pandemic diseases and any related company or government policies or actions; actions taken by the members of OPEC and Russia affecting the production and pricing of oil, as well as other domestic and global political, economic, or diplomatic developments, including any impact of the ongoing war in Ukraine and the Israel-Hamas war on the global energy markets and geopolitical stability; instability in the financial markets; inflationary pressures; higher interest rates and their impact on the cost of capital; regional supply and demand factors, including delays, curtailment delays or interruptions of production, or governmental orders, rules or regulations that impose production limits; federal and state legislative and regulatory initiatives relating to hydraulic fracturing, including the effect of existing and future laws and governmental regulations; physical and transition risks relating to climate change; those risks described in Item 1A of Diamondback’s Annual Report on Form 10-K, filed with the SEC on February 22, 2024, and those risks disclosed in its subsequent filings on Forms 10-Q and 8-K, which can be obtained free of charge on the SEC’s website at http://www.sec.gov and Diamondback’s website at www.diamondbackenergy.com/investors.

    In light of these factors, the events anticipated by Diamondback’s forward-looking statements may not occur at the time anticipated or at all. Moreover, Diamondback operates in a very competitive and rapidly changing environment and new risks emerge from time to time. Diamondback cannot predict all risks, nor can it assess the impact of all factors on its business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those anticipated by any forward-looking statements it may make. Accordingly, you should not place undue reliance on any forward-looking statements. All forward-looking statements speak only as of the date of this letter or, if earlier, as of the date they were made. Diamondback does not intend to, and disclaims any obligation to, update or revise any forward-looking statements unless required by applicable law.

     
    Diamondback Energy, Inc.
    Condensed Consolidated Balance Sheets
    (unaudited, in millions, except share amounts)
           
      September 30,   December 31,
        2024       2023  
    Assets      
    Current assets:      
    Cash and cash equivalents ($169 million and $26 million related to Viper) $ 370     $ 582  
    Restricted cash   3       3  
    Accounts receivable:      
    Joint interest and other, net   233       192  
    Oil and natural gas sales, net ($109 million and $109 million related to Viper)   1,197       654  
    Inventories   126       63  
    Derivative instruments   42       17  
    Prepaid expenses and other current assets   51       110  
    Total current assets   2,022       1,621  
    Property and equipment:      
    Oil and natural gas properties, full cost method of accounting ($21,971 million and $8,659 million excluded from amortization at September 30, 2024 and December 31, 2023, respectively) ($4,771 million and $4,629 million related to Viper and $1,623 million and $1,769 million excluded from amortization related to Viper)   79,718       42,430  
    Other property, equipment and land   1,417       673  
    Accumulated depletion, depreciation, amortization and impairment ($1,016 million and $866 million related to Viper)   (18,082 )     (16,429 )
    Property and equipment, net   63,053       26,674  
    Funds held in escrow   43        
    Equity method investments   377       529  
    Derivative instruments   38       1  
    Deferred income taxes, net   62       45  
    Investment in real estate, net   81       84  
    Other assets   71       47  
    Total assets $ 65,747     $ 29,001  
    Liabilities and Stockholders’ Equity      
    Current liabilities:      
    Accounts payable – trade $ 198     $ 261  
    Accrued capital expenditures   641       493  
    Current maturities of long-term debt   1,000        
    Other accrued liabilities   857       475  
    Revenues and royalties payable   1,444       764  
    Derivative instruments   34       86  
    Income taxes payable   289       29  
    Total current liabilities   4,463       2,108  
    Long-term debt ($822 million and $1,083 million related to Viper)   11,923       6,641  
    Derivative instruments   79       122  
    Asset retirement obligations   493       239  
    Deferred income taxes   9,952       2,449  
    Other long-term liabilities   18       12  
    Total liabilities   26,928       11,571  
    Stockholders’ equity:      
    Common stock, $0.01 par value; 800,000,000 shares authorized; 292,742,664 and 178,723,871 shares issued and outstanding at September 30, 2024 and December 31, 2023, respectively   3       2  
    Additional paid-in capital   34,007       14,142  
    Retained earnings (accumulated deficit)   3,427       2,489  
    Accumulated other comprehensive income (loss)   (8 )     (8 )
    Total Diamondback Energy, Inc. stockholders’ equity   37,429       16,625  
    Non-controlling interest   1,390       805  
    Total equity   38,819       17,430  
    Total liabilities and stockholders’ equity $ 65,747     $ 29,001  
     
    Diamondback Energy, Inc.
    Condensed Consolidated Statements of Operations
    (unaudited, $ in millions except per share data, shares in thousands)
                   
      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Revenues:              
    Oil, natural gas and natural gas liquid sales $ 2,354     $ 2,265     $ 6,629     $ 6,063  
    Sales of purchased oil   282       59       698       59  
    Other operating income   9       16       28       62  
    Total revenues   2,645       2,340       7,355       6,184  
    Costs and expenses:              
    Lease operating expenses   316       226       825       618  
    Production and ad valorem taxes   153       118       413       421  
    Gathering, processing and transportation   102       73       261       209  
    Purchased oil expense   280       59       696       59  
    Depreciation, depletion, amortization and accretion   742       442       1,694       1,277  
    General and administrative expenses   49       34       141       111  
    Merger and integration expense   258       1       273       11  
    Other operating expenses   35       47       68       113  
    Total costs and expenses   1,935       1,000       4,371       2,819  
    Income (loss) from operations   710       1,340       2,984       3,365  
    Other income (expense):              
    Interest expense, net   (18 )     (37 )     (101 )     (130 )
    Other income (expense), net   89       33       87       61  
    Gain (loss) on derivative instruments, net   131       (76 )     101       (358 )
    Gain (loss) on extinguishment of debt               2       (4 )
    Income (loss) from equity investments, net   6       9       23       39  
    Total other income (expense), net   208       (71 )     112       (392 )
    Income (loss) before income taxes   918       1,269       3,096       2,973  
    Provision for (benefit from) income taxes   210       276       685       648  
    Net income (loss)   708       993       2,411       2,325  
    Net income (loss) attributable to non-controlling interest   49       78       147       142  
    Net income (loss) attributable to Diamondback Energy, Inc. $ 659     $ 915     $ 2,264     $ 2,183  
                   
    Earnings (loss) per common share:              
    Basic $ 3.19     $ 5.07     $ 12.00     $ 12.01  
    Diluted $ 3.19     $ 5.07     $ 12.00     $ 12.01  
    Weighted average common shares outstanding:              
    Basic   204,730       178,872       187,253       180,400  
    Diluted   204,730       178,872       187,253       180,400  
     
    Diamondback Energy, Inc.
    Condensed Consolidated Statements of Cash Flows
    (unaudited, in millions)
                   
      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Cash flows from operating activities:              
    Net income (loss) $ 708     $ 993     $ 2,411     $ 2,325  
    Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:              
    Provision for (benefit from) deferred income taxes   51       10       180       185  
    Depreciation, depletion, amortization and accretion   742       442       1,694       1,277  
    (Gain) loss on extinguishment of debt               (2 )     4  
    (Gain) loss on derivative instruments, net   (131 )     76       (101 )     358  
    Cash received (paid) on settlement of derivative instruments   (4 )     (24 )     (36 )     (62 )
    (Income) loss from equity investment, net   (6 )     (9 )     (23 )     (39 )
    Equity-based compensation expense   16       13       49       40  
    Other   20       3       77       (23 )
    Changes in operating assets and liabilities:              
    Accounts receivable   106       (256 )     61       (218 )
    Income tax receivable         103       12       267  
    Prepaid expenses and other current assets   (11 )     (8 )     78       5  
    Accounts payable and accrued liabilities   (395 )     (28 )     (490 )     46  
    Income taxes payable   (36 )     23       (51 )     4  
    Revenues and royalties payable   95       53       109       139  
    Other   54       (33 )     104       (12 )
       Net cash provided by (used in) operating activities   1,209       1,358       4,072       4,296  
    Cash flows from investing activities:              
    Drilling, completions, infrastructure and midstream additions to oil and natural gas properties   (688 )     (684 )     (1,934 )     (2,052 )
    Property acquisitions   (7,791 )     (168 )     (7,994 )     (1,193 )
    Proceeds from sale of assets   207       868       459       1,400  
    Other   106       (1 )     103       (14 )
       Net cash provided by (used in) investing activities   (8,166 )     15       (9,366 )     (1,859 )
    Cash flows from financing activities:              
    Proceeds under term loan agreement   1,000             1,000        
    Proceeds from borrowings under credit facilities   1,011       1,015       1,185       4,466  
    Repayments under credit facilities   (1,073 )     (1,332 )     (1,333 )     (4,368 )
    Proceeds from senior notes               5,500        
    Repayment of senior notes               (25 )     (134 )
    Repurchased shares under buyback program   (515 )     (56 )     (557 )     (709 )
    Repurchased shares/units under Viper’s buyback program         (10 )           (67 )
    Proceeds from partial sale of investment in Viper Energy, Inc.               451        
    Net proceeds from Viper’s issuance of common stock   476             476        
    Dividends paid to stockholders   (416 )     (149 )     (1,316 )     (841 )
    Dividends/distributions to non-controlling interest   (59 )     (25 )     (157 )     (84 )
    Other   (5 )     (7 )     (142 )     (34 )
       Net cash provided by (used in) financing activities   419       (564 )     5,082       (1,771 )
    Net increase (decrease) in cash and cash equivalents   (6,538 )     809       (212 )     666  
    Cash, cash equivalents and restricted cash at beginning of period   6,911       21       585       164  
    Cash, cash equivalents and restricted cash at end of period $ 373     $ 830     $ 373     $ 830  
     
    Diamondback Energy, Inc.
    Selected Operating Data
    (unaudited)
               
      Three Months Ended
      September 30, 2024   June 30, 2024   September 30, 2023
    Production Data:          
    Oil (MBbls)   29,537       25,129       24,482  
    Natural gas (MMcf)   66,519       51,310       49,423  
    Natural gas liquids (MBbls)   11,918       9,514       8,943  
    Combined volumes (MBOE)(1)   52,541       43,195       41,662  
               
    Daily oil volumes (BO/d)   321,054       276,143       266,109  
    Daily combined volumes (BOE/d)   571,098       474,670       452,848  
               
    Average Prices:          
    Oil ($ per Bbl) $ 73.13     $ 79.51     $ 81.57  
    Natural gas ($ per Mcf) $ (0.26 )   $ 0.10     $ 1.62  
    Natural gas liquids ($ per Bbl) $ 17.70     $ 17.97     $ 21.02  
    Combined ($ per BOE) $ 44.80     $ 50.33     $ 54.37  
               
    Oil, hedged ($ per Bbl)(2) $ 72.32     $ 78.55     $ 80.51  
    Natural gas, hedged ($ per Mcf)(2) $ 0.60     $ 1.03     $ 1.62  
    Natural gas liquids, hedged ($ per Bbl)(2) $ 17.70     $ 17.97     $ 21.02  
    Average price, hedged ($ per BOE)(2) $ 45.43     $ 50.89     $ 53.74  
               
    Average Costs per BOE:          
    Lease operating expenses $ 6.01     $ 5.88     $ 5.42  
    Production and ad valorem taxes   2.91       3.26       2.83  
    Gathering, processing and transportation expense   1.94       1.90       1.75  
    General and administrative – cash component   0.63       0.63       0.51  
    Total operating expense – cash $ 11.49     $ 11.67     $ 10.51  
               
    General and administrative – non-cash component $ 0.30     $ 0.44     $ 0.31  
    Depreciation, depletion, amortization and accretion per BOE $ 14.12     $ 11.18     $ 10.61  
    Interest expense, net $ 0.34     $ 1.02     $ 0.89  

    (1)   Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.
    (2)   Hedged prices reflect the effect of our commodity derivative transactions on our average sales prices and include gains and losses on cash settlements for matured commodity derivatives, which we do not designate for hedge accounting. Hedged prices exclude gains or losses resulting from the early settlement of commodity derivative contracts.


    NON-GAAP FINANCIAL MEASURES

    ADJUSTED EBITDA

    Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. The Company defines Adjusted EBITDA as net income (loss) attributable to Diamondback Energy, Inc., plus net income (loss) attributable to non-controlling interest (“net income (loss)”) before non-cash (gain) loss on derivative instruments, net, interest expense, net, depreciation, depletion, amortization and accretion, depreciation and interest expense related to equity method investments, (gain) loss on extinguishment of debt, if any, non-cash equity-based compensation expense, capitalized equity-based compensation expense, merger and integration expenses, other non-cash transactions and provision for (benefit from) income taxes, if any. Adjusted EBITDA is not a measure of net income as determined by United States generally accepted accounting principles (“GAAP”). Management believes Adjusted EBITDA is useful because the measure allows it to more effectively evaluate the Company’s operating performance and compare the results of its operations from period to period without regard to its financing methods or capital structure. The Company adds the items listed above to net income (loss) to determine Adjusted EBITDA because these amounts can vary substantially from company to company within its industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Further, the Company excludes the effects of significant transactions that may affect earnings but are unpredictable in nature, timing and amount, although they may recur in different reporting periods. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of the Company’s operating performance or liquidity. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets. The Company’s computation of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies or to such measure in our credit facility or any of our other contracts.

    The following tables present a reconciliation of the GAAP financial measure of net income (loss) attributable to Diamondback Energy, Inc. to the non-GAAP financial measure of Adjusted EBITDA:

    Diamondback Energy, Inc.
    Reconciliation of Net Income (Loss) to Adjusted EBITDA
    (unaudited, in millions)
               
      Three Months Ended
      September 30, 2024   June 30, 2024   September 30, 2023
    Net income (loss) attributable to Diamondback Energy, Inc. $ 659     $ 837     $ 915  
    Net income (loss) attributable to non-controlling interest   49       57       78  
    Net income (loss)   708       894       993  
    Non-cash (gain) loss on derivative instruments, net   (135 )     (46 )     52  
    Interest expense, net   18       44       37  
    Depreciation, depletion, amortization and accretion   742       483       442  
    Depreciation and interest expense related to equity method investments   15       23       18  
    Non-cash equity-based compensation expense   24       26       21  
    Capitalized equity-based compensation expense   (8 )     (7 )     (8 )
    Merger and integration expenses   258       3       1  
    Other non-cash transactions   (72 )     6       (12 )
    Provision for (benefit from) income taxes   210       252       276  
    Consolidated Adjusted EBITDA   1,760       1,678       1,820  
    Less: Adjustment for non-controlling interest   104       103       78  
    Adjusted EBITDA attributable to Diamondback Energy, Inc. $ 1,656     $ 1,575     $ 1,742  


    ADJUSTED NET INCOME

    Adjusted net income is a non-GAAP financial measure equal to net income (loss) attributable to Diamondback Energy, Inc. plus net income (loss) attributable to non-controlling interest (“net income (loss)”) adjusted for non-cash (gain) loss on derivative instruments, net, (gain) loss on extinguishment of debt, if any, merger and integration expense, other non-cash transactions and related income tax adjustments, if any. The Company’s computation of adjusted net income may not be comparable to other similarly titled measures of other companies or to such measure in our credit facility or any of our other contracts. Management believes adjusted net income helps investors in the oil and natural gas industry to measure and compare the Company’s performance to other oil and natural gas companies by excluding from the calculation items that can vary significantly from company to company depending upon accounting methods, the book value of assets and other non-operational factors. Further, in order to allow investors to compare the Company’s performance across periods, the Company excludes the effects of significant transactions that may affect earnings but are unpredictable in nature, timing and amount, although they may recur in different reporting periods.

    The following table presents a reconciliation of the GAAP financial measure of net income (loss) attributable to Diamondback Energy, Inc. to the non-GAAP measure of adjusted net income:

    Diamondback Energy, Inc.
    Adjusted Net Income
    (unaudited, $ in millions except per share data, shares in thousands)
       
      Three Months Ended September 30, 2024
      Amounts   Amounts Per
    Diluted Share
    Net income (loss) attributable to Diamondback Energy, Inc.(1) $ 659     $ 3.19  
    Net income (loss) attributable to non-controlling interest   49       0.24  
    Net income (loss)(1)   708       3.43  
    Non-cash (gain) loss on derivative instruments, net   (135 )     (0.66 )
    Merger and integration expense   258       1.26  
    Other non-cash transactions   (72 )     (0.35 )
    Adjusted net income excluding above items(1)   759       3.68  
    Income tax adjustment for above items   (12 )     (0.06 )
    Adjusted net income(1)   747       3.62  
    Less: Adjusted net income attributable to non-controlling interest   49       0.24  
    Adjusted net income attributable to Diamondback Energy, Inc.(1) $ 698     $ 3.38  
           
    Weighted average common shares outstanding:      
    Basic     204,730  
    Diluted     204,730  

    (1) The Company’s earnings (loss) per diluted share amount has been computed using the two-class method in accordance with GAAP. The two-class method is an earnings allocation which reflects the respective ownership among holders of common stock and participating securities. Diluted earnings per share using the two-class method is calculated as (i) net income attributable to Diamondback Energy, Inc, (ii) less the reallocation of $6 million in earnings attributable to participating securities, (iii) divided by diluted weighted average common shares outstanding.


    OPERATING CASH FLOW BEFORE WORKING CAPITAL CHANGES AND FREE CASH FLOW

    Operating cash flow before working capital changes, which is a non-GAAP financial measure, represents net cash provided by operating activities as determined under GAAP without regard to changes in operating assets and liabilities. The Company believes operating cash flow before working capital changes is a useful measure of an oil and natural gas company’s ability to generate cash used to fund exploration, development and acquisition activities and service debt or pay dividends. The Company also uses this measure because changes in operating assets and liabilities relate to the timing of cash receipts and disbursements that the Company may not control and may not relate to the period in which the operating activities occurred. This allows the Company to compare its operating performance with that of other companies without regard to financing methods and capital structure.

    Free Cash Flow, which is a non-GAAP financial measure, is cash flow from operating activities before changes in working capital in excess of cash capital expenditures. The Company believes that Free Cash Flow is useful to investors as it provides measures to compare both cash flow from operating activities and additions to oil and natural gas properties across periods on a consistent basis as adjusted for non-recurring tax impacts from divestitures, merger and integration expenses, the early termination of derivative contracts and settlements of treasury locks. These measures should not be considered as an alternative to, or more meaningful than, net cash provided by operating activities as an indicator of operating performance. The Company’s computation of Free Cash Flow may not be comparable to other similarly titled measures of other companies. The Company uses Free Cash Flow to reduce debt, as well as return capital to stockholders as determined by the Board of Directors.

    The following tables present a reconciliation of the GAAP financial measure of net cash provided by operating activities to the non-GAAP measure of operating cash flow before working capital changes and to the non-GAAP measure of Free Cash Flow:

    Diamondback Energy, Inc.
    Operating Cash Flow Before Working Capital Changes and Free Cash Flow
    (unaudited, in millions)
                   
      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Net cash provided by operating activities $ 1,209     $ 1,358     $ 4,072     $ 4,296  
    Less: Changes in cash due to changes in operating assets and liabilities:              
    Accounts receivable   106       (256 )     61       (218 )
    Income tax receivable         103       12       267  
    Prepaid expenses and other current assets   (11 )     (8 )     78       5  
    Accounts payable and accrued liabilities   (395 )     (28 )     (490 )     46  
    Income taxes payable   (36 )     23       (51 )     4  
    Revenues and royalties payable   95       53       109       139  
    Other   54       (33 )     104       (12 )
    Total working capital changes   (187 )     (146 )     (177 )     231  
    Operating cash flow before working capital changes   1,396       1,504       4,249       4,065  
    Drilling, completions, infrastructure and midstream additions to oil and natural gas properties   (688 )     (684 )     (1,934 )     (2,052 )
    Total Cash CAPEX   (688 )     (684 )     (1,934 )     (2,052 )
    Free Cash Flow   708       820       2,315       2,013  
    Tax impact from divestitures(1)         64             64  
    Merger and integration expenses   258             273        
    Early termination of derivatives   37             37        
    Treasury locks               25        
    Adjusted Free Cash Flow $ 1,003     $ 884     $ 2,650     $ 2,077  

    (1) Includes the tax impact for the disposal of certain Midland Basin water assets and Delaware Basin oil gathering assets.


    NET DEBT

    The Company defines the non-GAAP measure of net debt as total debt (excluding debt issuance costs, discounts, premiums and unamortized basis adjustments) less cash and cash equivalents. Net debt should not be considered an alternative to, or more meaningful than, total debt, the most directly comparable GAAP measure. Management uses net debt to determine the Company’s outstanding debt obligations that would not be readily satisfied by its cash and cash equivalents on hand. The Company believes this metric is useful to analysts and investors in determining the Company’s leverage position because the Company has the ability to, and may decide to, use a portion of its cash and cash equivalents to reduce debt.

    Diamondback Energy, Inc.
    Net Debt
    (unaudited, in millions)
                           
      September 30,
    2024
      Net Q3
    Principal
    Borrowings/
    (Repayments)
      June 30,
    2024
      March 31,
    2024
      December 31,
    2023
      September 30,
    2023
      (in millions)
    Diamondback Energy, Inc.(1) $ 12,284     $ 1,115     $ 11,169     $ 5,669     $ 5,697     $ 5,697  
    Viper Energy, Inc.(1)   830       (177 )     1,007       1,103       1,093       680  
    Total debt   13,114     $ 938       12,176       6,772       6,790       6,377  
    Cash and cash equivalents   (370 )         (6,908 )     (896 )     (582 )     (827 )
    Net debt $ 12,744         $ 5,268     $ 5,876     $ 6,208     $ 5,550  

    (1)  Excludes debt issuance costs, discounts, premiums and unamortized basis adjustments.


    DERIVATIVES

    As of November 1, 2024, the Company had the following outstanding consolidated derivative contracts, including derivative contracts at Viper Energy, Inc. The Company’s derivative contracts are based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on New York Mercantile Exchange West Texas Intermediate pricing and Crude Oil Brent pricing and with natural gas derivative settlements based on the New York Mercantile Exchange Henry Hub pricing. When aggregating multiple contracts, the weighted average contract price is disclosed.

      Crude Oil (Bbls/day, $/Bbl)
      Q4 2024   Q1 2025   Q2 2025   Q3 2025   Q4 2025   FY2026
    Long Puts – Crude Brent Oil 82,000   52,000   33,000   10,000    
    Long Put Price ($/Bbl) $57.44   $60.00   $60.00   $60.00    
    Deferred Premium ($/Bbl) $-1.52   $-1.48   $-1.50   $-1.63    
    Long Puts – WTI (Magellan East Houston) 35,000   58,000   46,000   22,000    
    Long Put Price ($/Bbl) $57.57   $56.21   $55.22   $55.00    
    Deferred Premium ($/Bbl) $-1.61   $-1.58   $-1.56   $-1.64    
    Long Puts – WTI (Cushing) 125,000   138,000   109,000   38,000    
    Long Put Price ($/Bbl) $57.28   $56.63   $55.73   $55.00    
    Deferred Premium ($/Bbl) $-1.61   $-1.58   $-1.56   $-1.50    
    Costless Collars – WTI (Cushing) 46,000   13,000        
    Long Put Price ($/Bbl) $60.87   $60.00        
    Short Call Price ($/Bbl) $89.91   $89.55        
    Basis Swaps – WTI (Midland) 43,000   58,000   45,000   45,000   45,000  
    $1.18   $1.10   $1.08   $1.08   $1.08  
    Roll Swaps – WTI 40,000          
    $0.82          
      Natural Gas (Mmbtu/day, $/Mmbtu)
      Q4 2024   Q1 2025   Q2 2025   Q3 2025   Q4 2025   FY 2026
    Costless Collars – Henry Hub 398,261   690,000   630,000   630,000   630,000   80,000
    Long Put Price ($/Mmbtu) $2.78   $2.53   $2.49   $2.49   $2.49   $2.50
    Ceiling Price ($/Mmbtu) $6.53   $5.41   $5.46   $5.46   $5.46   $5.95
    Natural Gas Swaps – Henry Hub 13,370          
    $3.23          
    Natural Gas Basis Swaps – Waha Hub 471,630   650,000   590,000   590,000   590,000   10,000
    $-1.11   $-0.80   $-0.83   $-0.83   $-0.83   $-1.25

    Investor Contact:
    Adam Lawlis
    +1 432.221.7467
    alawlis@diamondbackenergy.com

    The MIL Network

  • MIL-OSI: Letter to Stockholders Issued By Diamondback Energy, Inc.

    Source: GlobeNewswire (MIL-OSI)

    MIDLAND, Texas, Nov. 04, 2024 (GLOBE NEWSWIRE) —

    Diamondback Stockholders,

    This letter is meant to be a supplement to our earnings release and is being furnished to the Securities and Exchange Commission (SEC) and released to our stockholders simultaneously with our earnings release. Please see the information regarding forward-looking statements and non-GAAP financial information included at the end of this letter.

    Endeavor Closing:
    Diamondback closed the Endeavor transaction on September 10th, which began the next chapter of the Company’s short history. In just under two months, the Diamondback and Endeavor teams have worked quickly towards a seamless integration. We onboarded more than 1,000 employees, moved over 650 combined offices and began working as one functional organization in the first week post-close.

    The teams have already begun sharing best practices, which we witnessed in our first pro forma quarterly operations reviews a few weeks ago. At a high level, we have essentially merged two teams of basin experts. While we were once competitors, we can now share best practices and learnings from years of drilling and completing wells in the Midland Basin with what we believe is more combined data and basin experience than any competitor. This is a synergy that could not be modeled in our spreadsheet when the deal was announced, but I am confident this will accrue to the benefit of our stockholders in short order.

    We are ahead of schedule in delivering the operational synergies we promised in conjunction with the merger. Our drilling and completions teams have already implemented the two most significant operational synergies: clear fluids for drilling and SimulFrac for completions. All our development in the fourth quarter will be executed with SimulFrac completions crews, with spot crews to be used for single-well tests like the Barnett Shale in the Midland Basin. On the drilling side, as of today, all of our rigs are operating with clear fluid drilling systems, and we have already seen wells on legacy Endeavor acreage drilled below post-synergy-expected cost per lateral foot.

    At time of deal announcement, we promised to drill and complete wells for $625 per lateral foot in 2025 on Endeavor’s acreage. I can say that today, in real time and two months post-announcement, we are averaging $600 per lateral foot across the combined Company – above expectations and ahead of schedule.

    We are also actively learning from the Endeavor teams. On the execution front, we are optimistic about application and integration of some early learnings around the post-completion, drill-out process and believe there to be significant best practices to be shared across the combined production operations groups. We are also closely studying the various completion designs from the two companies and are confident the combination of the best completion design with the lowest cost execution will be a winning formula.

    As a result, I could not be more excited about the early progress from integration and remain confident in the team’s ability to meet or exceed the synergies promised at deal announcement.

    TRP Energy (“TRP”) Asset Trade:
    Our new combined acreage footprint has given us the flexibility to look at different opportunities across the Permian Basin. This is exemplified by a trade we just executed, where we signed an exchange agreement with TRP that allows us to play offense in our backyard by swapping a PDP-heavy asset in the Delaware Basin for a Midland Basin asset with more near-term development potential. In exchange for our Vermejo asset and ~$238 million in cash, we will receive TRP’s Midland Basin asset, which consists of approximately 15,000 net acres located in Upton and Reagan counties. The asset we will acquire in this trade has 55 remaining undeveloped operated locations, the majority of which compete for capital right away. The trade is expected to be accretive to our 2025 Cash Flow and Free Cash Flow per share and will high grade our inventory. We expect this trade to close by year-end, subject to customary regulatory approvals and closing conditions.

    We will also continue to look for ways to improve our asset base, whether it be through traditional trades to be able to drill longer laterals and increase operated working interests or “out of the box” ideas such as TRP.

    Third Quarter Operational Performance:
    I am proud of our team’s ability to execute regardless of the circumstances and the third quarter was no exception. Our team put operations first even as many moved offices, integrated new team members and began to understand a large new asset. We are currently running 20 drilling rigs and expect to be down to 18 operated rigs by year-end. What we originally expected to drill with 22 – 24 rigs in 2025, we now expect we can drill with closer to 18 rigs. This is purely based on continued efficiency gains, a testament to the prowess of our drilling organization.

    On the completions side of the business, we are currently running four SimulFrac crews, three of which are electric. We continue to exceed our original key performance indicators for 2024. We are completing on average nearly 4,000 lateral feet per day per crew, 30% more than we originally planned heading into the year. This increase is driven by higher pumping hours per day, higher average pump rates, lower swap times per stage and faster move times between pads.

    Production:
    For the quarter, Diamondback produced 321.1 MBO/d (571.1 MBOE/d), above the high end of the guidance range of 319 – 321 MBO/d (565 – 569 MBOE/d) that we released in October. As a reminder, this third quarter production incorporates twenty-one days of legacy Endeavor production. Well performance continues to meet or exceed expectations in our core Midland Basin position, setting us up well to continue to execute and achieve additional capital efficiency gains.

    For the fourth quarter of 2024, we expect to produce 470 – 475 MBO/d (840 – 850 MBOE/d). This includes a minor contribution from Viper’s closed acquisition of Tumbleweed. It also shows we expect to hit pro forma production expectations sooner than originally expected.

    Capital Expenditures:
    In the third quarter, we spent $688 million on capital expenditures, which is in the middle of our updated guidance range of $675 – $700 million. For the fourth quarter, we expect to spend $950 – $1,050 million of capex.

    The macro environment for oil prices and near-term global oil supply and demand dynamics remains volatile at best and tenuous at worst. Diamondback’s base case 2025 plan is still what was laid out with the Endeavor merger announcement in February (“generate oil production of 470 – 480 MBO/d (800 – 825 MBOE/d) with a capital budget of approximately $4.1 – $4.4 billion”), with oil production expected to increase by approximately 5 MBO/d due to contribution from the Viper Tumbleweed acquisition.

    On the other hand, we are actively working all our options for 2025, including continuing to refine this base case plan. Should oil prices weaken from current levels, we will make the correct capital allocation decision and focus on Free Cash Flow generation and capital efficiency over oil volumes. Our size, scale, cost structure and inventory quality position us well for whatever direction the macro decides to take. Our return of capital program, combined with a strong balance sheet, allows us to increase stockholder returns when volatility increases.

    Operating Costs:
    Total cash operating costs decreased slightly quarter over quarter to $11.49 per BOE. Lease operating expense (“LOE”) in the third quarter was $6.01 per BOE, within our annual guidance range of $5.90 – $6.40 per BOE. Cash G&A was $0.63 within our annual guidance range of $0.55 – $0.65 per BOE. We have announced a preliminary look at run rate pro forma operating expenses and expect to solidify these numbers when we update the market for 2025 unit cost guidance. DD&A increased quarter over quarter to $14.12 as a result of the Endeavor assets being added to our balance sheet.

    Financial Performance and Return of Capital:
    Diamondback generated $1.2 billion of net cash provided by operating activities and operating cash flow before working capital changes of $1.4 billion. Adjusted Free Cash Flow was $1.0 billion. Unique to this quarter, we adjusted Free Cash Flow upwards to account for two one-time items: $258 million of merger and integration expense and $37 million of costs associated with unwinding a portion of our outstanding swap to floating interest rate hedges.

    We will return ~78% of that Adjusted Free Cash Flow to stockholders through our base dividend and share repurchases. Our willingness to go above our base 50% return threshold was driven by our opportunistic share repurchase program, as we bought back ~$515 million worth of common stock at an average price of $176.40 / share in the third quarter. This includes 2 million shares repurchased for ~$350 million at a price of $175.11 per share in conjunction with the September secondary offering, where legacy Endeavor stockholders sold approximately 14.4 million shares. Diamondback’s participation in the offering is consistent with our opportunistic repurchase methodology, leaning into our repurchase program when we view our stock to be attractively valued at mid-cycle oil pricing.

    We have continued to be active repurchasing shares in the fourth quarter, and quarter to date have bought back over $185 million worth of shares at an average share price of approximately $180.13.

    As previously announced, our Board recently increased our share repurchase authorization to $6.0 billion from $4.0 billion previously. This gives us the flexibility to allocate capital appropriately and buy back shares in times of market stress.

    Balance Sheet:
    At quarter-end, we had approximately $13.1 billion of gross debt and $12.7 billion of net debt. We ended the quarter with $2.6 billion of liquidity at Diamondback, as we increased our borrowing base and elected commitments on our revolving credit facility to $2.5 billion from $1.6 billion previously.

    In September, we also received upgrades from two of the three rating agencies, as S&P upgraded us to BBB from BBB- and Fitch moved us to BBB+ from BBB. Moody’s remained at Baa2.

    As we have stated previously, our near-term goal is to lower consolidated net debt below $10 billion, which we expect to achieve through Free Cash Flow generation and proceeds from non-core asset sales. Our long-term priority is to maintain a leverage ratio of approximately 0.5x at mid-cycle oil pricing, or approximately $6 to $8 billion of net debt. We feel we can achieve this goal within the next couple of years solely by dedicating 50% of Free Cash Flow to debt paydown, while reserving the ability to flex up stockholder returns through opportunistic stock repurchases at times of excessive market volatility or one-time events such as secondary equity sell-downs.

    Other Business:
    We continue to use our equity method investments as valuable tools to improve our core operating business while also generating impressive returns, adding significant cash to our balance sheet. As we previously announced in July, Energy Transfer LP completed its acquisition of WTG Midstream Holdings LLC (“WTG”). Additionally, during the third quarter we completed the sale of our 4% interest in the Wink to Webster Pipeline.

    With the sales of WTG and Wink to Webster complete, we now have three equity method investments remaining in our portfolio: the EPIC crude pipeline (“EPIC”), the BANGL Y-grade NGL pipeline and the Deep Blue sustainable water management company. We recently increased our ownership in EPIC from 10.0% to 27.5% and are excited about the growth potential of this long-haul crude pipe as well as our other investments. As such, we do not feel now is the right time to monetize these assets.

    We continue to believe we can add significant value to our minerals company Viper (NASDAQ: VNOM) and Deep Blue through the potential drop down of Endeavor overrides and minerals to Viper and the sale of Endeavor’s extensive water infrastructure to Deep Blue, potentially accelerating our de-leveraging efforts in early 2025.

    We are also excited about what we see as the next wave of equity method investments for Diamondback: power generation and potentially data center development. By leveraging our 65,000 surface acres in West Texas, cheap natural gas and abundant supply of produced water, we believe we can be a premier partner in this new wave of development. By generating our own in-basin power, we can solve two long-term issues that have plagued the Permian Basin: the need for natural gas egress and cheap, reliable electricity. We look forward to updating our stockholders on our progress on these initiatives in the coming quarters.

    Closing:
    2024 has been a transformative year for Diamondback. We are intensely focused on delivering on the promises we made to the market around synergies and believe, eight weeks in, we have a significant head start relative to original expectations.

    Thank you for your ongoing support and interest in Diamondback Energy.

    Travis D. Stice
    Chairman of the Board and Chief Executive Officer

    Investor Contact:
    Adam Lawlis
    +1 432.221.7467
    alawlis@diamondbackenergy.com

    Forward-Looking Statements:

    This letter contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act of 1934, as amended, which involve risks, uncertainties, and assumptions. All statements, other than statements of historical fact, including statements regarding future performance; business strategy; future operations (including drilling plans and capital plans); estimates and projections of revenues, losses, costs, expenses, returns, cash flow, and financial position; reserve estimates and its ability to replace or increase reserves; anticipated benefits or other effects of strategic transactions (including the recently completed Endeavor merger and other acquisitions or divestitures); the expected amount and timing of synergies from the Endeavor merger; and plans and objectives of management (including plans for future cash flow from operations and for executing environmental strategies) are forward-looking statements. When used in this letter, the words “aim,” “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,” “intend,” “may,” “model,” “outlook,” “plan,” “positioned,” “potential,” “predict,” “project,” “seek,” “should,” “target,” “will,” “would,” and similar expressions (including the negative of such terms) are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Although Diamondback believes that the expectations and assumptions reflected in its forward-looking statements are reasonable as and when made, they involve risks and uncertainties that are difficult to predict and, in many cases, beyond Diamondback’s control. Accordingly, forward-looking statements are not guarantees of future performance and actual outcomes could differ materially from what Diamondback has expressed in its forward-looking statements.

    Factors that could cause the outcomes to differ materially include (but are not limited to) the following: changes in supply and demand levels for oil, natural gas, and natural gas liquids, and the resulting impact on the price for those commodities; the impact of public health crises, including epidemic or pandemic diseases and any related company or government policies or actions; actions taken by the members of OPEC and Russia affecting the production and pricing of oil, as well as other domestic and global political, economic, or diplomatic developments, including any impact of the ongoing war in Ukraine and the Israel-Hamas war on the global energy markets and geopolitical stability; instability in the financial markets; concerns over a potential economic slowdown or recession; inflationary pressures; higher interest rates and their impact on the cost of capital; regional supply and demand factors, including delays, curtailment delays or interruptions of production, or governmental orders, rules or regulations that impose production limits; federal and state legislative and regulatory initiatives relating to hydraulic fracturing, including the effect of existing and future laws and governmental regulations; physical and transition risks relating to climate change; those risks described in Item 1A of Diamondback’s Annual Report on Form 10-K, filed with the SEC on February 22, 2024, and those risks disclosed in its subsequent filings on Forms 10-Q and 8-K, which can be obtained free of charge on the SEC’s website at http://www.sec.gov and Diamondback’s website at www.diamondbackenergy.com/investors.

    In light of these factors, the events anticipated by Diamondback’s forward-looking statements may not occur at the time anticipated or at all. Moreover, Diamondback operates in a very competitive and rapidly changing environment and new risks emerge from time to time. Diamondback cannot predict all risks, nor can it assess the impact of all factors on its business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those anticipated by any forward-looking statements it may make. Accordingly, you should not place undue reliance on any forward-looking statements. All forward-looking statements speak only as of the date of this letter or, if earlier, as of the date they were made. Diamondback does not intend to, and disclaims any obligation to, update or revise any forward-looking statements unless required by applicable law.

    Non-GAAP Financial Measures

    This letter includes financial information not prepared in conformity with generally accepted accounting principles (GAAP), including free cash flow. The non-GAAP information should be considered by the reader in addition to, but not instead of, financial information prepared in accordance with GAAP. A reconciliation of the differences between these non-GAAP financial measures and the most directly comparable GAAP financial measures can be found in Diamondback’s quarterly results posted on Diamondback’s website at www.diamondbackenergy.com/investors/. Furthermore, this letter includes or references certain forward-looking, non-GAAP financial measures. Because Diamondback provides these measures on a forward-looking basis, it cannot reliably or reasonably predict certain of the necessary components of the most directly comparable forward-looking GAAP financial measures, such as future impairments and future changes in working capital. Accordingly, Diamondback is unable to present a quantitative reconciliation of such forward-looking, non-GAAP financial measures to the respective most directly comparable forward-looking GAAP financial measures. Diamondback believes that these forward-looking, non-GAAP measures may be a useful tool for the investment community in comparing Diamondback’s forecasted financial performance to the forecasted financial performance of other companies in the industry.

    The MIL Network

  • MIL-OSI: NXP Semiconductors Reports Third Quarter 2024 Results

    Source: GlobeNewswire (MIL-OSI)

    EINDHOVEN, The Netherlands, Nov. 04, 2024 (GLOBE NEWSWIRE) — NXP Semiconductors N.V. (NASDAQ: NXPI) today reported financial results for the third quarter, which ended September 29, 2024. “NXP delivered quarterly revenue of $3.25 billion, in-line with our overall guidance. While we experienced some strength against our expectations in the Communication Infrastructure, Mobile and Automotive end markets, we were confronted with increasing macro related weakness in the Industrial & IoT market. Our guidance for the fourth quarter reflects broader macro weakness especially in Europe and the Americas. We focus on managing what is in our control enabling NXP to drive resilient profitability and earnings in an uncertain demand environment,” said Kurt Sievers, NXP President and Chief Executive Officer.

    Key Highlights for the Third Quarter 2024:

    • Revenue was $3.25 billion, down 5 percent year-on-year;
    • GAAP gross margin was 57.4 percent, GAAP operating margin was 30.5 percent and GAAP diluted Net Income per Share was $2.79;
    • Non-GAAP gross margin was 58.2 percent, non-GAAP operating margin was 35.5 percent, and non-GAAP diluted Net Income per Share was $3.45;
    • Cash flow from operations was $779 million, with net capex investments of $186 million, resulting in non-GAAP free cash flow of $593 million;
    • During the third quarter of 2024, NXP continued to execute its capital return policy with the payment of $259 million in cash dividends, and the repurchase of $305 million of its common shares. The total capital return of $564 million in the quarter represented 95 percent of third quarter non-GAAP free cash flow. On a trailing twelve month basis, capital return to shareholders represented $2.4 billion or 87 percent of non-GAAP free cash flow. The interim dividend for the third quarter 2024 was paid in cash on October 9, 2024 to shareholders of record as of September 12, 2024. On August 29th, the NXP board of directors authorized an additional $2.0 billion for share repurchases, resulting in a $2.64 billion share repurchase balance at the end of the third quarter. Subsequent to the end of the third quarter, between September 30, 2024 and November 1, 2024, NXP executed via a 10b5-1 program additional share repurchases totaling $117 million;
    • On August 20, 2024, ESMC, the previously announced manufacturing joint venture between TSMC, Robert Bosch GmbH, Infineon Technologies AG and NXP Semiconductors N.V. held a groundbreaking ceremony to mark the initial phase of construction of its first semiconductor fab in Dresden, Germany;
    • On September 4, 2024, Vanguard International Semiconductor Corporation and NXP Semiconductors N.V. announced the receipt of all necessary governmental approvals from relevant authorities and injected capital to officially establish the previously announced VisionPower Semiconductor Manufacturing Company Pte Ltd (VSMC) manufacturing joint venture. The company will now proceed with the planned construction of VSMC’s first 300mm wafer manufacturing facility;
    • On September 10, 2024, NXP announced the Trimension® SR250, the industry’s first single-chip, UWB solution to enable Industrial and IoT applications that integrates on-chip processing capabilities with both short-range UWB-based radar and secure ranging;
    • On September 17, 2024, NXP announced the MC33777, the world’s first electric vehicle battery junction box IC that consolidates essential BMS functions into a single device; and
    • On September 24, 2024, NXP announced the new i.MX RT700 crossover MCU family, designed to power smart AI-enabled edge devices, such as wearables, consumer medical devices, smart home devices and HMI platforms.

    Summary of Reported Third Quarter 2024 ($ millions, unaudited) (1)

      Q3 2024
      Q2 2024
      Q3 2023    Q – Q   Y – Y
    Total Revenue $ 3,250     $ 3,127     $ 3,434     4%   -5%
    GAAP Gross Profit $ 1,866     $ 1,792     $ 1,965     4%   -5%
    Gross Profit Adjustments(i) $ (26 )   $ (41 )   $ (45 )        
    Non-GAAP Gross Profit $ 1,892     $ 1,833     $ 2,010     3%   -6%
    GAAP Gross Margin   57.4 %     57.3 %     57.2 %        
    Non-GAAP Gross Margin   58.2 %     58.6 %     58.5 %        
    GAAP Operating Income (Loss) $ 990     $ 896     $ 992     10%   —%
    Operating Income Adjustments(i) $ (163 )   $ (175 )   $ (211 )        
    Non-GAAP Operating Income $ 1,153     $ 1,071     $ 1,203     8%   -4%
    GAAP Operating Margin   30.5 %     28.7 %     28.9 %        
    Non-GAAP Operating Margin   35.5 %     34.3 %     35.0 %        
    GAAP Net Income (Loss) attributable to Stockholders $ 718     $ 658     $ 787          
    Net Income Adjustments(i) $ (172 )   $ (171 )   $ (178 )        
    Non-GAAP Net Income (Loss) Attributable to Stockholders $ 890     $ 829     $ 965          
    GAAP diluted Net Income (Loss) per Share(ii) $ 2.79     $ 2.54     $ 3.01          
    Non-GAAP diluted Net Income (Loss) per Share(ii) $ 3.45     $ 3.20     $ 3.70          
    Additional information
      Q3 2024
      Q2 2024
      Q3 2023
      Q – Q   Y – Y
    Automotive $ 1,829     $ 1,728     $ 1,891     6%   -3%
    Industrial & IoT $ 563     $ 616     $ 607     -9%   -7%
    Mobile $ 407     $ 345     $ 377     18%   8%
    Comm. Infra. & Other $ 451     $ 438     $ 559     3%   -19%
    DIO   149       148       134          
    DPO   60       64       60          
    DSO   30       27       25          
    Cash Conversion Cycle   119       111       99          
    Channel Inventory (weeks / months)   8 / 1.9       7 / 1.7       7 / 1.5          
    Gross Financial Leverage(iii)   1.9x       1.9x       2.1x          
    Net Financial Leverage(iv)   1.3x       1.3x       1.3x          
                                   
    1. Additional Information for the Third Quarter 2024:
      1. For an explanation of GAAP to non-GAAP adjustments, please see “Non-GAAP Financial Measures”.
      2. Refer to Table 1 below for the weighted average number of diluted shares for the presented periods.
      3. Gross financial leverage is defined as gross debt divided by trailing twelve months adjusted EBITDA.
      4. Net financial leverage is defined as net debt divided by trailing twelve months adjusted EBITDA.

    Guidance for the Fourth Quarter 2024: ($ millions, except Per Share data) (1)

                  Guidance Range              
      GAAP   Reconciliation   non-GAAP
      Low   Mid   High       Low   Mid   High
    Total Revenue $3,000   $3,100   $3,200       $3,000   $3,100     $3,200
    Q-Q -8%   -5%   -2%       -8%   -5     -2%
    Y-Y -12%   -9%   -6%       -12%   -9     -6%
    Gross Profit $1,674   $1,746   $1,820   $(35)   $1,709   $1,781     $1,855
    Gross Margin 55.8%   56.3%   56.9%       57.0%   57.5%     58.0%
    Operating Income (loss) $810   $872   $936   $(184)   $994   $1,056     $1,120
    Operating Margin 27.0%   28.1%   29.3%       33.1%   34.1%     35.0%
    Financial Income (expense) $(87)   $(87)   $(87)   $(10)   $(77)   $(77)     $(77)
    Tax rate 17.2%-18.2%       16.3%-17.3%
    NCI & Other $(14)   $(14)   $(14)   $(3)   $(11)   $(11)     $(11)
    Shares – diluted 257.0   257.0   257.0       257.0   257.0     257.0
    Earnings Per Share – diluted $2.26   $2.46   $2.66       $2.93   $3.13     $3.33
                                 

    Note (1) Additional Information:

    1. GAAP Gross Profit is expected to include Purchase Price Accounting (“PPA”) effects, $(10) million; Share-based Compensation, $(15) million; Other Incidentals, $(10) million;
    2. GAAP Operating Income (loss) is expected to include PPA effects, $(39) million; Share-based Compensation, $(118) million; Restructuring and Other Incidentals, $(27) million;
    3. GAAP Financial Income (expense) is expected to include Other financial expense $(10) million;
    4. GAAP Non-Controlling Interest (NCI) and Other is expected to include results relating to non-foundry equity-accounted investees $(3) million;
    5. GAAP diluted EPS is expected to include the adjustments noted above for PPA effects, Share-based Compensation, Restructuring and Other Incidentals in GAAP Operating Income (loss), the adjustment for Other financial expense, the adjustment for Non-controlling interest & Other and the adjustment on Tax due to the earlier mentioned adjustments.

    NXP has based the guidance included in this release on judgments and estimates that management believes are reasonable given its assessment of historical trends and other information reasonably available as of the date of this release. Please note, the guidance included in this release consists of predictions only, and is subject to a wide range of known and unknown risks and uncertainties, many of which are beyond NXP’s control. The guidance included in this release should not be regarded as representations by NXP that the estimated results will be achieved. Actual results may vary materially from the guidance we provide today. In relation to the use of non-GAAP financial information see the note regarding “Non-GAAP Financial Measures” below. For the factors, risks, and uncertainties to which judgments, estimates and forward-looking statements generally are subject see the note regarding “Forward-looking Statements.” We undertake no obligation to publicly update or revise any forward-looking statements, including the guidance set forth herein, to reflect future events or circumstances.

    Non-GAAP Financial Measures

    In managing NXP’s business on a consolidated basis, management develops an annual operating plan, which is approved by our Board of Directors, using non-GAAP financial measures, that are not in accordance with, nor an alternative to, U.S. generally accepted accounting principles (“GAAP”). In measuring performance against this plan, management considers the actual or potential impacts on these non-GAAP financial measures from actions taken to reduce costs with the goal of increasing our gross margin and operating margin and when assessing appropriate levels of research and development efforts. In addition, management relies upon these non-GAAP financial measures when making decisions about product spending, administrative budgets, and other operating expenses. We believe that these non-GAAP financial measures, when coupled with the GAAP results and the reconciliations to corresponding GAAP financial measures, provide a more complete understanding of the Company’s results of operations and the factors and trends affecting NXP’s business. We believe that they enable investors to perform additional comparisons of our operating results, to assess our liquidity and capital position and to analyze financial performance excluding the effect of expenses unrelated to core operating performance, certain non-cash expenses and share-based compensation expense, which may obscure trends in NXP’s underlying performance. This information also enables investors to compare financial results between periods where certain items may vary independent of business performance, and allow for greater transparency with respect to key metrics used by management.

    These non-GAAP financial measures are provided in addition to, and not as a substitute for, or superior to, measures of financial performance prepared in accordance with GAAP. The presentation of these and other similar items in NXP’s non-GAAP financial results should not be interpreted as implying that these items are non-recurring, infrequent, or unusual. Reconciliations of these non-GAAP measures to the most comparable measures calculated in accordance with GAAP are provided in the financial statements portion of this release in a schedule entitled “Financial Reconciliation of GAAP to non-GAAP Results (unaudited).” Please refer to the NXP Historic Financial Model file found on the Financial Information page of the Investor Relations section of our website at https://investors.nxp.com for additional information related to our rationale for using these non-GAAP financial measures, as well as the impact of these measures on the presentation of NXP’s operations.

    In addition to providing financial information on a basis consistent with GAAP, NXP also provides the following selected financial measures on a non-GAAP basis: (i) Gross profit, (ii) Gross margin, (iii) Research and development, (iv) Selling, general and administrative, (v) Amortization of acquisition-related intangible assets, (vi) Other income, (vii) Operating income (loss), (viii) Operating margin, (ix) Financial Income (expense), (x) Income tax benefit (provision), (xi) Results relating to non-foundry equity-accounted investees, (xii) Net income (loss) attributable to stockholders, (xiii) Earnings per Share – Diluted, (xiv) EBITDA, adjusted EBITDA and trailing 12 month adjusted EBITDA, and (xv) free cash flow, trailing 12 month free cash flow and trailing 12 month free cash flow as a percent of Revenue. The non-GAAP information excludes, where applicable, the amortization of acquisition related intangible assets, the purchase accounting effect on inventory and property, plant and equipment, merger related costs (including integration costs), certain items related to divestitures, share-based compensation expense, restructuring and asset impairment charges, extinguishment of debt, foreign exchange gains and losses, income tax effect on adjustments described above and results from non-foundry equity-accounted investments.

    The difference in the benefit (provision) for income taxes between our GAAP and non-GAAP results relates to the income tax effects of the GAAP to non-GAAP adjustments that we make and the income tax effect of any discrete items that occur in the interim period. Discrete items primarily relate to unexpected tax events that may occur as these amounts cannot be forecasted (e.g., the impact of changes in tax law and/or rates, changes in estimates or resolved tax audits relating to prior year tax provisions, the excess or deficit tax effects on share-based compensation, etc.).

    Conference Call and Webcast Information

    The company will host a conference call with the financial community on Tuesday, November 5, 2024 at 8:00 a.m. U.S. Eastern Standard Time (EST) to review the third quarter 2024 results in detail.

    Interested parties may preregister to obtain a user-specific access code for the call here.

    The call will be webcast and can be accessed from the NXP Investor Relations website at www.nxp.com. A replay of the call will be available on the NXP Investor Relations website within 24 hours of the actual call.

    About NXP Semiconductors

    NXP Semiconductors N.V. (NASDAQ: NXPI) is the trusted partner for innovative solutions in the automotive, industrial & IoT, mobile, and communications infrastructure markets. NXP’s “Brighter Together” approach combines leading-edge technology with pioneering people to develop system solutions that make the connected world better, safer, and more secure. The company has operations in more than 30 countries and posted revenue of $13.28 billion in 2023. Find out more at www.nxp.com.

    Forward-looking Statements

    This document includes forward-looking statements which include statements regarding NXP’s business strategy, financial condition, results of operations, market data, as well as any other statements which are not historical facts. By their nature, forward-looking statements are subject to numerous factors, risks and uncertainties that could cause actual outcomes and results to be materially different from those projected. These factors, risks and uncertainties include the following: market demand and semiconductor industry conditions; our ability to successfully introduce new technologies and products; the demand for the goods into which NXP’s products are incorporated; trade disputes between the U.S. and China, potential increase of barriers to international trade and resulting disruptions to NXP’s established supply chains; the impact of government actions and regulations, including restrictions on the export of US-regulated products and technology; increasing and evolving cybersecurity threats and privacy risks, including theft of sensitive or confidential data; the ability to generate sufficient cash, raise sufficient capital or refinance corporate debt at or before maturity to meet both NXP’s debt service and research and development and capital investment requirements; our ability to accurately estimate demand and match our production capacity accordingly or obtain supplies from third-party producers to meet demand; our access to production capacity from third-party outsourcing partners, and any events that might affect their business or NXP’s relationship with them; our ability to secure adequate and timely supply of equipment and materials from suppliers; our ability to avoid operational problems and product defects and, if such issues were to arise, to correct them quickly; our ability to form strategic partnerships and joint ventures and to successfully cooperate with our alliance partners; our ability to win competitive bid selection processes; our ability to develop products for use in customers’ equipment and products; the ability to successfully hire and retain key management and senior product engineers; global hostilities, including the invasion of Ukraine by Russia and resulting regional instability, sanctions and any other retaliatory measures taken against Russia and the continued hostilities and the armed conflict in the Middle East, which could adversely impact the global supply chain, disrupt our operations or negatively impact the demand for our products in our primary end markets; the ability to maintain good relationships with NXP’s suppliers; and a change in tax laws could have an effect on our estimated effective tax rate. In addition, this document contains information concerning the semiconductor industry, our end markets and business generally, which is forward-looking in nature and is based on a variety of assumptions regarding the ways in which the semiconductor industry, our end markets and business will develop. NXP has based these assumptions on information currently available, if any one or more of these assumptions turn out to be incorrect, actual results may differ from those predicted. While NXP does not know what impact any such differences may have on its business, if there are such differences, its future results of operations and its financial condition could be materially adversely affected. Readers are cautioned not to place undue reliance on these forward-looking statements, which speak to results only as of the date the statements were made. Except for any ongoing obligation to disclose material information as required by the United States federal securities laws, NXP does not have any intention or obligation to publicly update or revise any forward-looking statements after we distribute this document, whether to reflect any future events or circumstances or otherwise. For a discussion of potential risks and uncertainties, please refer to the risk factors listed in our SEC filings. Copies of our SEC filings are available on our Investor Relations website, www.nxp.com/investor or from the SEC website, www.sec.gov.

    For further information, please contact:
       
    Investors: Media:
    Jeff Palmer Paige Iven
    jeff.palmer@nxp.com paige.iven@nxp.com
    +1 408 205 0687  +1 817 975 0602

    NXP-CORP

    NXP Semiconductors
    Table 1: Condensed consolidated statement of operations (unaudited)

    ($ in millions except share data) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
               
    Revenue $ 3,250     $ 3,127     $ 3,434  
    Cost of revenue   (1,384 )     (1,335 )     (1,469 )
    Gross profit   1,866       1,792       1,965  
    Research and development   (577 )     (594 )     (601 )
    Selling, general and administrative   (265 )     (270 )     (294 )
    Amortization of acquisition-related intangible assets   (29 )     (28 )     (71 )
    Total operating expenses   (871 )     (892 )     (966 )
    Other income (expense)   (5 )     (4 )     (7 )
    Operating income (loss)   990       896       992  
    Financial income (expense):          
    Extinguishment of debt                
    Other financial income (expense)   (82 )     (75 )     (75 )
    Income (loss) before income taxes   908       821       917  
    Benefit (provision) for income taxes   (173 )     (154 )     (123 )
    Results relating to equity-accounted investees   (6 )     (3 )     (2 )
    Net income (loss)   729       664       792  
    Less: Net income (loss) attributable to non-controlling interests   11       6       5  
    Net income (loss) attributable to stockholders   718       658       787  
               
    Earnings per share data:          
    Net income (loss) per common share attributable to stockholders in $
    Basic $ 2.82     $ 2.58     $ 3.06  
    Diluted $ 2.79     $ 2.54     $ 3.01  
               
    Weighted average number of shares of common stock outstanding during the period (in thousands):
    Basic   254,458       255,478       257,488  
    Diluted   257,717       258,732       261,095  
               

    NXP Semiconductors
    Table 2: Condensed consolidated balance sheet (unaudited)

    ($ in millions) As of
      September 29, 2024   June 30, 2024   October 1, 2023
    ASSETS          
    Current assets:          
    Cash and cash equivalents $ 2,748     $ 2,859     $ 4,042  
    Short-term deposits   400       400        
    Accounts receivable, net   1,070       927       939  
    Inventories, net   2,234       2,148       2,140  
    Other current assets   574       546       495  
    Total current assets   7,026       6,880       7,616  
               
    Non-current assets:          
    Other non-current assets   2,641       2,290       2,236  
    Property, plant and equipment, net   3,309       3,289       3,197  
    Identified intangible assets, net   735       796       1,010  
    Goodwill   9,958       9,941       9,937  
    Total non-current assets   16,643       16,316       16,380  
               
    Total assets   23,669       23,196       23,996  
               
    LIABILITIES AND EQUITY          
    Current liabilities:          
    Accounts payable   899       929       959  
    Restructuring liabilities-current   52       62       16  
    Other current liabilities   1,542       1,622       1,990  
    Short-term debt   499       499       999  
    Total current liabilities   2,992       3,112       3,964  
               
    Non-current liabilities:          
    Long-term debt   9,683       9,681       10,173  
    Restructuring liabilities   4       7       3  
    Deferred tax liabilities   57       48       44  
    Other non-current liabilities   1,189       1,003       1,014  
    Total non-current liabilities   10,933       10,739       11,234  
               
    Non-controlling interests   338       327       310  
    Stockholders’ equity   9,406       9,018       8,488  
    Total equity   9,744       9,345       8,798  
               
    Total liabilities and equity   23,669       23,196       23,996  
               

    NXP Semiconductors
    Table 3: Condensed consolidated statement of cash flows (unaudited)

    ($ in millions) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
    Cash flows from operating activities:          
    Net income (loss) $ 729     $ 664     $ 792  
    Adjustments to reconcile net income (loss) to net cash provided by (used for) operating activities:          
    Depreciation and amortization   218       213       273  
    Share-based compensation   115       114       103  
    Amortization of discount (premium) on debt, net         1       1  
    Amortization of debt issuance costs   2       1       2  
    Results relating to equity-accounted investees   6       3       2  
    (Gain) loss on equity securities, net   7       3       4  
    Deferred tax expense (benefit)   (40 )     (23 )     (33 )
    Changes in operating assets and liabilities:          
    (Increase) decrease in receivables and other current assets   (167 )     10       40  
    (Increase) decrease in inventories   (86 )     (46 )     (34 )
    Increase (decrease) in accounts payable and other liabilities   118       (220 )     (128 )
    (Increase) decrease in other non-current assets   (134 )     40       (49 )
    Exchange differences   7       5       5  
    Other items   4       (4 )     10  
    Net cash provided by (used for) operating activities   779       761       988  
    Cash flows from investing activities:          
    Purchase of identified intangible assets   (26 )     (55 )     (42 )
    Capital expenditures on property, plant and equipment   (186 )     (185 )     (200 )
    Proceeds from the disposals of property, plant and equipment         1        
    Purchase of investments   (159 )           (31 )
    Net cash provided by (used for) investing activities   (371 )     (239 )     (273 )
    Cash flows from financing activities:          
    Dividends paid to common stockholders   (259 )     (260 )     (262 )
    Proceeds from issuance of common stock through stock plans   39       3       36  
    Purchase of treasury shares and restricted stock unit
    withholdings
      (305 )     (310 )     (306 )
    Other, net   (1 )           (1 )
    Net cash provided by (used for) financing activities   (526 )     (567 )     (533 )
    Effect of changes in exchange rates on cash positions   7       (4 )     (3 )
    Increase (decrease) in cash and cash equivalents   (111 )     (49 )     179  
    Cash and cash equivalents at beginning of period   2,859       2,908       3,863  
    Cash and cash equivalents at end of period   2,748       2,859       4,042  
               
    Net cash paid during the period for:          
    Interest   27       86       38  
    Income taxes, net of refunds   196       193       165  
    Net gain (loss) on sale of assets:          
    Cash proceeds from the sale of assets         1        
    Book value of these assets         (1 )      
    Non-cash investing activities:          
    Non-cash capital expenditures   125       166       167  
               

    NXP Semiconductors
    Table 4: Financial Reconciliation of GAAP to non-GAAP Results (unaudited)

    ($ in millions except share data) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
    GAAP Gross Profit $ 1,866     $ 1,792     $ 1,965  
    PPA Effects   (12 )     (12 )     (13 )
    Restructuring         (4 )      
    Share-based compensation   (14 )     (15 )     (14 )
    Other incidentals         (10 )     (18 )
    Non-GAAP Gross Profit $ 1,892     $ 1,833     $ 2,010  
    GAAP Gross margin   57.4 %     57.3 %     57.2 %
    Non-GAAP Gross margin   58.2 %     58.6 %     58.5 %
    GAAP Research and development $ (577 )   $ (594 )   $ (601 )
    Restructuring         (4 )     4  
    Share-based compensation   (58 )     (58 )     (53 )
    Other incidentals               (2 )
    Non-GAAP Research and development $ (519 )   $ (532 )   $ (550 )
    GAAP Selling, general and administrative $ (265 )   $ (270 )   $ (294 )
    PPA effects   (1 )     (1 )     (1 )
    Restructuring         2        
    Share-based compensation   (43 )     (41 )     (36 )
    Other incidentals   (2 )     (2 )     (4 )
    Non-GAAP Selling, general and administrative $ (219 )   $ (228 )   $ (253 )
    GAAP Operating income (loss) $ 990     $ 896     $ 992  
    PPA effects   (42 )     (41 )     (85 )
    Restructuring         (6 )     4  
    Share-based compensation   (115 )     (114 )     (103 )
    Other incidentals   (6 )     (14 )     (27 )
    Non-GAAP Operating income (loss) $ 1,153     $ 1,071     $ 1,203  
    GAAP Operating margin   30.5 %     28.7 %     28.9 %
    Non-GAAP Operating margin   35.5 %     34.3 %     35.0 %
    GAAP Income tax benefit (provision) $ (173 )   $ (154 )   $ (123 )
    Income tax effect   9       15       45  
    Non-GAAP Income tax benefit (provision) $ (182 )   $ (169 )   $ (168 )
    GAAP Net income (loss) attributable to stockholders $ 718     $ 658     $ 787  
    PPA Effects   (42 )     (41 )     (85 )
    Restructuring         (6 )     4  
    Share-based compensation   (115 )     (114 )     (103 )
    Other incidentals   (6 )     (14 )     (27 )
    Other adjustments:          
    Adjustments to financial income (expense)   (12 )     (8 )     (10 )
    Income tax effect   9       15       45  
    Results relating to equity-accounted investees, excluding Foundry investees1   (6 )     (3 )     (2 )
    Non-GAAP Net income (loss) attributable to stockholders $ 890     $ 829     $ 965  
               
               
    Additional Information:          
    1. Refer to Table 7 below for further information regarding the results relating to equity-accounted investees.
               
    GAAP net income (loss) per common share attributable to stockholders – diluted $ 2.79     $ 2.54     $ 3.01  
    PPA Effects   (0.16 )     (0.16 )     (0.33 )
    Restructuring         (0.02 )     0.01  
    Share-based compensation   (0.45 )     (0.44 )     (0.40 )
    Other incidentals   (0.02 )     (0.06 )     (0.10 )
    Other adjustments:          
    Adjustments to financial income (expense)   (0.05 )     (0.03 )     (0.03 )
    Income tax effect   0.04       0.06       0.17  
    Results relating to equity-accounted investees, excluding Foundry investees1   (0.02 )     (0.01 )     (0.01 )
    Non-GAAP net income (loss) per common share attributable to stockholders – diluted $ 3.45     $ 3.20     $ 3.70  
               
               
    Additional Information:          
    1. Refer to Table 7 below for further information regarding the results relating to equity-accounted investees.

    NXP Semiconductors
    Table 5: Financial Reconciliation of GAAP to non-GAAP Financial income (expense) (unaudited)

    ($ in millions) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
    GAAP Financial income (expense) $ (82 )   $ (75 )   $ (75 )
    Foreign exchange loss   (3 )     (2 )     (3 )
    Other financial expense   (9 )     (6 )     (7 )
    Non-GAAP Financial income (expense) $ (70 )   $ (67 )   $ (65 )
               

    NXP Semiconductors
    Table 6: Financial Reconciliation of GAAP to non-GAAP Other income (expense) (unaudited)

    ($ in millions) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
    GAAP Other income (expense) $ (5 )   $ (4 )   $ (7 )
    Other incidentals   (4 )     (2 )     (3 )
    Non-GAAP Other income (expense) $ (1 )   $ (2 )   $ (4 )
               

    NXP Semiconductors
    Table 7: Financial Reconciliation of GAAP to non-GAAP Results relating to equity-accounted investees (unaudited)

    ($ in millions) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
    GAAP Results relating to equity-accounted investees $ (6 )   $ (3 )   $ (2 )
    Results of equity-accounted investees, excluding Foundry investees1   (6 )     (3 )     (2 )
    Non-GAAP Results relating to equity-accounted investees $     $     $  
               
    Additional Information:
    1. We adjust our results relating to equity-accounted investees for those results from investments over which NXP has significant influence, but not control, and whose business activities are not related to the core operating performance of NXP. Our equity-investments in foundry partners are part of our long-term core operating performance and accordingly those results comprise the Non-GAAP Results relating to equity-accounted investees.

    NXP Semiconductors
    Table 8: Adjusted EBITDA and Free Cash Flow (unaudited)

    ($ in millions) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
    GAAP Net income (loss) $ 729     $ 664     $ 792  
    Reconciling items to EBITDA (Non-GAAP)          
    Financial (income) expense   82       75       75  
    (Benefit) provision for income taxes   173       154       123  
    Depreciation   149       146       163  
    Amortization   69       67       110  
    EBITDA (Non-GAAP) $ 1,202     $ 1,106     $ 1,263  
    Reconciling items to adjusted EBITDA (Non-GAAP)          
    Results of equity-accounted investees, excluding Foundry investees1   6       3       2  
    Restructuring         6       (4 )
    Share-based compensation   115       114       103  
    Other incidental items   6       14       27  
    Adjusted EBITDA (Non-GAAP) $ 1,329     $ 1,243     $ 1,391  
    Trailing twelve month adjusted EBITDA (Non-GAAP)   5,235       5,297       5,384  
               
               
    Additional Information:          
    1. Refer to Table 7 above for further information regarding the results relating to equity-accounted investees.
               
               
    ($ in millions) Three months ended
      September 29, 2024   June 30, 2024   October 1, 2023
    Net cash provided by (used for) operating activities $ 779     $ 761     $ 988  
    Net capital expenditures on property, plant and equipment   (186 )     (184 )     (200 )
    Non-GAAP free cash flow $ 593     $ 577     $ 788  
    Trailing twelve month non-GAAP free cash flow $ 2,759     $ 2,954     $ 2,568  
    Trailing twelve month non-GAAP free cash flow as percent of Revenue   21 %     23 %     20 %
               

    The MIL Network

  • MIL-OSI: Par Pacific Holdings Reports Third Quarter 2024 Results

    Source: GlobeNewswire (MIL-OSI)

    HOUSTON, Nov. 04, 2024 (GLOBE NEWSWIRE) — Par Pacific Holdings, Inc. (NYSE: PARR) (“Par Pacific” or the “Company”) today reported its financial results for the quarter ended September 30, 2024.

    • Net Income of $7.5 million, or $0.13 per diluted share
    • Adjusted Net Loss of $(5.5) million, or $(0.10) per diluted share
    • Adjusted EBITDA of $51.4 million
    • Record logistics financial results driven by record refining throughput
    • Liquidity increased by $112.1 million while repurchasing $21.9 million of common stock

    Par Pacific reported net income of $7.5 million, or $0.13 per diluted share, for the quarter ended September 30, 2024, compared to $171.4 million, or $2.79 per diluted share, for the same quarter in 2023. Third quarter 2024 Adjusted Net Loss was $(5.5) million, compared to Adjusted Net Income of $193.4 million in the third quarter of 2023. Third quarter 2024 Adjusted EBITDA was $51.4 million, compared to $255.7 million in the third quarter of 2023. A reconciliation of reported non-GAAP financial measures to their most directly comparable GAAP financial measures can be found in the tables accompanying this news release.

    “Our third quarter financial results reflect a challenging summer refining margin environment,” said Will Monteleone, President and Chief Executive Officer. “Despite the cyclical downturn, refining system throughput set a quarterly record, our retail and logistics segments delivered consistently strong financial results, and our Hawaii SAF project has entered the construction phase. We are focused on improving operating and capital efficiency while prioritizing safe and reliable operations.”

    Refining

    The Refining segment reported operating income of $19.0 million in the third quarter of 2024, compared to $194.8 million in the third quarter of 2023. Adjusted Gross Margin for the Refining segment was $142.2 million in the third quarter of 2024, compared to $350.6 million in the third quarter of 2023.

    Refining segment Adjusted EBITDA was $20.1 million in the third quarter of 2024, compared to $233.6 million in the third quarter of 2023.

    Hawaii
    The 3-1-2 Singapore Crack Spread was $11.00 per barrel in the third quarter of 2024, compared to $23.39 per barrel in the third quarter of 2023. Throughput in the third quarter of 2024 was 81 thousand barrels per day (Mbpd), compared to 82 Mbpd for the same quarter in 2023. Production costs were $4.58 per throughput barrel in the third quarter of 2024, compared to $4.50 per throughput barrel in the same period of 2023.

    The Hawaii refinery’s Adjusted Gross Margin was $6.10 per barrel during the third quarter of 2024, including a net price lag impact of approximately $5.1 million, or $0.68 per barrel, compared to $13.47 per barrel during the third quarter of 2023.

    Montana
    The RVO Adjusted USGC 3-2-1 Index averaged $14.14 per barrel in the third quarter of 2024, compared to $29.65 in the third quarter of 2023. The Montana refinery’s throughput in the third quarter of 2024 was 57 Mbpd, compared to 55 Mbpd for the same quarter in 2023. Production costs were $11.61 per throughput barrel, compared to $10.83 per throughput barrel in the same period of 2023.

    The Montana refinery’s Adjusted Gross Margin was $12.42 per barrel during the third quarter of 2024, compared to $26.49 per barrel during the third quarter of 2023.

    Washington
    The RVO Adjusted Pacific Northwest 3-1-1-1 Index averaged $15.48 per barrel in the third quarter of 2024, compared to $35.00 per barrel in the third quarter of 2023. The Washington refinery’s throughput was 41 Mbpd in the third quarter of 2024, compared to 41 Mbpd in the third quarter of 2023. Production costs were $3.50 per throughput barrel in the third quarter of 2024, compared to $3.77 per throughput barrel in the same period of 2023.

    The Washington refinery’s Adjusted Gross Margin was $1.76 per barrel during the third quarter of 2024, compared to $12.30 per barrel during the third quarter of 2023.

    Wyoming
    The RVO Adjusted USGC 3-2-1 Index averaged $14.14 per barrel in the third quarter of 2024, compared to $29.65 per barrel in the third quarter of 2023. The Wyoming refinery’s throughput was 19 Mbpd in the third quarter of 2024, compared to 20 Mbpd in the third quarter of 2023. Production costs were $7.00 per throughput barrel in the third quarter of 2024, compared to $6.46 per throughput barrel in the same period of 2023.

    The Wyoming refinery’s Adjusted Gross Margin was $13.65 per barrel during the third quarter of 2024, including a FIFO impact of approximately $(4.7) million, or $(2.63) per barrel, compared to $37.01 per barrel during the third quarter of 2023.

    Retail

    The Retail segment reported operating income of $18.3 million in the third quarter of 2024, compared to $13.3 million in the third quarter of 2023. Adjusted Gross Margin for the Retail segment was $42.6 million in the third quarter of 2024, compared to $38.2 million in the same quarter of 2023.

    Retail segment Adjusted EBITDA was $21.0 million in the third quarter of 2024, compared to $16.7 million in the third quarter of 2023. The Retail segment reported sales volumes of 31.2 million gallons in the third quarter of 2024, compared to 31.1 million gallons in the same quarter of 2023. Third quarter 2024 same store sales fuel volumes decreased by (1.4)% while merchandise revenue increased by 3.8%, compared to third quarter of 2023.

    Logistics

    The Logistics segment reported operating income of $26.2 million in the third quarter of 2024, compared to $20.7 million in the third quarter of 2023. Adjusted Gross Margin for the Logistics segment was $36.3 million in the third quarter of 2024, compared to $35.3 million in the same quarter of 2023.

    Logistics segment Adjusted EBITDA was $33.0 million in the third quarter of 2024, compared to $29.1 million in the third quarter of 2023.

    Liquidity

    Net cash provided by operations totaled $78.5 million for the three months ended September 30, 2024, including working capital inflows of $67.2 million and deferred turnaround expenditures of $(15.6) million. Excluding these items, net cash provided by operations was $26.9 million for the three months ended September 30, 2024. Net cash provided by operations was $269.2 million for the three months ended September 30, 2023. Net cash used in investing activities totaled $(28.3) million for the three months ended September 30, 2024, consisting primarily of capital expenditures, compared to $(5.7) million for the three months ended September 30, 2023. Net cash used in financing activities totaled $(46.8) million for the three months ended September 30, 2024, compared to $(92.9) million for the three months ended September 30, 2023.

    At September 30, 2024, Par Pacific’s cash balance totaled $183.0 million, gross term debt was $546.0 million, and total liquidity was $632.5 million. Net term debt was $363.0 million at September 30, 2024. In the third quarter of 2024, the Company repurchased $21.9 million of common stock.

    Laramie Energy

    In conjunction with Laramie Energy LLC’s (“Laramie’s”) refinancing and subsequent cash distribution to Par Pacific during the first quarter of 2023, we resumed the application of equity method accounting for our investment in Laramie effective February 21, 2023. During the third quarter of 2024, we recorded $(0.3) million of equity losses. Laramie’s total net loss was $(4.2) million in the third quarter of 2024, including unrealized losses on derivatives of $(0.4) million, compared to $(4.7) million in the third quarter of 2023. Laramie’s total Adjusted EBITDAX was $9.9 million in the third quarter of 2024, compared to $15.4 million in the third quarter of 2023.

    Conference Call Information

    A conference call is scheduled for Tuesday, November 5, 2024 at 9:00 a.m. Central Time (10:00 a.m. Eastern Time). To access the call, please dial 1-833-974-2377 inside the U.S. or 1-412-317-5782 outside of the U.S. and ask for the Par Pacific call. Please dial in at least 10 minutes early to register. The webcast may be accessed online through the Company’s website at http://www.parpacific.com on the Investors page. A telephone replay will be available until November 19, 2024 and may be accessed by calling 1-877-344-7529 inside the U.S. or 1-412-317-0088 outside the U.S. and using the conference ID 4223997.

    About Par Pacific

    Par Pacific Holdings, Inc. (NYSE: PARR), headquartered in Houston, Texas, is a growing energy company providing both renewable and conventional fuels to the western United States. Par Pacific owns and operates 219,000 bpd of combined refining capacity across four locations in Hawaii, the Pacific Northwest and the Rockies, and an extensive energy infrastructure network, including 13 million barrels of storage, and marine, rail, rack, and pipeline assets. In addition, Par Pacific operates the Hele retail brand in Hawaii and the “nomnom” convenience store chain in the Pacific Northwest. Par Pacific also owns 46% of Laramie Energy, LLC, a natural gas production company with operations and assets concentrated in Western Colorado. More information is available at www.parpacific.com.

    Forward-Looking Statements

    This news release (and oral statements regarding the subject matter of this news release, including those made on the conference call and webcast announced herein) includes certain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, which are intended to qualify for the “safe harbor” from liability established by the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact are forward-looking statements. Forward-looking statements include, without limitation, statements about: expected market conditions; anticipated free cash flows; anticipated refinery throughput; anticipated cost savings; anticipated capital expenditures, including major maintenance costs, and their effect on our financial and operating results, including earnings per share and free cash flow; anticipated retail sales volumes and on-island sales; the anticipated financial and operational results of Laramie Energy, LLC; the amount of our discounted net cash flows and the impact of our NOL carryforwards thereon; our ability to identify, acquire, and develop energy, related retailing, and infrastructure businesses; the timing and expected results of certain development projects, as well as the impact of such investments on our product mix and sales; the anticipated synergies and other benefits of the Billings refinery and associated marketing and logistics assets (“Billings Acquisition”), including renewable growth opportunities, the anticipated financial and operating results of the Billings Acquisition and the effect on Par Pacific’s cash flows and profitability (including Adjusted EBITDA and Adjusted Net Income and Free Cash Flow per share); and other risks and uncertainties detailed in our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q and any other documents that we file with the Securities and Exchange Commission. Additionally, forward-looking statements are subject to certain risks, trends, and uncertainties, such as changes to our financial condition and liquidity; the volatility of crude oil and refined product prices; the Russia-Ukraine war, Israel-Palestine conflict, Houthi attacks in the Red Sea, Iranian activities in the Strait of Hormuz and their potential impacts on global crude oil markets and our business; operating disruptions at our refineries resulting from unplanned maintenance events or natural disasters; environmental risks; changes in the labor market; and risks of political or regulatory changes. We cannot provide assurances that the assumptions upon which these forward-looking statements are based will prove to have been correct. Should one of these risks materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those expressed or implied in any forward-looking statements, and investors are cautioned not to place undue reliance on these forward-looking statements, which are current only as of this date. We do not intend to update or revise any forward-looking statements made herein or any other forward-looking statements as a result of new information, future events, or otherwise. We further expressly disclaim any written or oral statements made by a third party regarding the subject matter of this news release.

    Contact:
    Ashimi Patel
    VP, Investor Relations & Sustainability
    (832) 916-3355
    apatel@parpacific.com

     
    Condensed Consolidated Statements of Operations
    (Unaudited)
    (in thousands, except per share data)
     
      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Revenues $ 2,143,933     $ 2,579,308     $ 6,142,236     $ 6,048,444  
    Operating expenses              
    Cost of revenues (excluding depreciation)   1,905,200       2,174,385       5,422,875       5,038,211  
    Operating expense (excluding depreciation)   147,049       145,183       444,389       330,146  
    Depreciation and amortization   31,879       35,311       96,679       87,887  
    General and administrative expense (excluding depreciation)   22,399       23,694       87,322       66,148  
    Equity earnings from refining and logistics investments   (3,008 )     (3,934 )     (12,846 )     (4,359 )
    Acquisition and integration costs   (23 )     4,669       68       17,213  
    Par West redevelopment and other costs   4,006       3,127       9,048       8,490  
    Loss on sale of assets, net               114        
    Total operating expenses   2,107,502       2,382,435       6,047,649       5,543,736  
    Operating income   36,431       196,873       94,587       504,708  
    Other income (expense)              
    Interest expense and financing costs, net   (23,402 )     (20,815 )     (61,720 )     (51,974 )
    Debt extinguishment and commitment costs               (1,418 )     (17,682 )
    Other income (loss), net   1,253       (43 )     (1,447 )     301  
    Equity earnings (losses) from Laramie Energy, LLC   (336 )           2,867       10,706  
    Total other expense, net   (22,485 )     (20,858 )     (61,718 )     (58,649 )
    Income before income taxes   13,946       176,015       32,869       446,059  
    Income tax expense   (6,460 )     (4,600 )     (10,496 )     (6,741 )
    Net income $ 7,486     $ 171,415     $ 22,373     $ 439,318  
    Weighted-average shares outstanding              
    Basic   55,729       60,223       57,283       60,241  
    Diluted   56,224       61,404       58,070       61,144  
                   
    Income per share              
    Basic $ 0.13     $ 2.85     $ 0.39     $ 7.29  
    Diluted $ 0.13     $ 2.79     $ 0.39     $ 7.18  
     
    Balance Sheet Data
    (Unaudited)
    (in thousands)
     
      September 30, 2024   December 31, 2023
    Balance Sheet Data      
    Cash and cash equivalents $ 182,977   $ 279,107
    Working capital (1)   542,690     190,042
    ABL Credit Facility   511,000     115,000
    Term debt (2)   546,021     550,621
    Total debt, including current portion   1,043,706     650,858
    Total stockholders’ equity   1,254,026     1,335,424

    ______________________________
    (1)   Working capital is calculated as (i) total current assets excluding cash and cash equivalents less (ii) total current liabilities excluding current portion of long-term debt. Total current assets include inventories stated at the lower of cost or net realizable value.
    (2)   Term debt includes the Term Loan Credit Agreement and other long-term debt.


    Operating Statistics

    The following table summarizes key operational data:

      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Total Refining Segment              
    Feedstocks throughput (Mbpd) (1)   198.4       198.2       186.3       164.6  
    Refined product sales volume (Mbpd) (1)   216.2       217.3       200.2       178.7  
                   
    Hawaii Refinery              
    Feedstocks throughput (Mbpd)   80.7       82.3       80.4       80.9  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   25.6 %     26.5 %     26.0 %     26.7 %
    Distillates   38.3 %     42.1 %     38.1 %     40.8 %
    Fuel oils   32.0 %     26.5 %     32.0 %     28.0 %
    Other products   0.7 %     2.1 %     0.3 %     1.5 %
    Total yield   96.6 %     97.2 %     96.4 %     97.0 %
                   
    Refined product sales volume (Mbpd)   93.5       90.0       87.8       89.2  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 6.10     $ 13.47     $ 10.06     $ 14.74  
    Production costs per bbl ($/throughput bbl) (3)   4.58       4.50       4.66       4.46  
    D&A per bbl ($/throughput bbl)   0.25       0.65       0.47       0.68  
                   
    Montana Refinery              
    Feedstocks Throughput (Mbpd) (1)   57.2       55.4       49.2       57.1  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   46.5 %     50.5 %     49.5 %     49.6 %
    Distillates   34.7 %     27.7 %     31.7 %     28.2 %
    Asphalt   11.0 %     14.7 %     9.3 %     14.4 %
    Other products   4.0 %     3.4 %     4.4 %     3.5 %
    Total yield   96.2 %     96.3 %     94.9 %     95.7 %
                   
    Refined product sales volume (Mbpd) (1)   60.3       63.5       53.4       62.5  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 12.42     $ 26.49     $ 14.15     $ 27.74  
    Production costs per bbl ($/throughput bbl) (3)   11.61       10.83       13.16       10.10  
    D&A per bbl ($/throughput bbl)   1.82       1.63       1.69       1.69  
                   
      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Washington Refinery              
    Feedstocks throughput (Mbpd)   41.1       41.0       37.9       40.5  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   23.6 %     22.8 %     24.0 %     23.4 %
    Distillate   35.3 %     34.6 %     34.5 %     34.6 %
    Asphalt   17.4 %     20.1 %     18.6 %     19.4 %
    Other products   19.7 %     18.8 %     19.3 %     18.8 %
    Total yield   96.0 %     96.3 %     96.4 %     96.2 %
                   
    Refined product sales volume (Mbpd)   42.4       44.2       39.6       43.3  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 1.76     $ 12.30     $ 4.03     $ 9.91  
    Production costs per bbl ($/throughput bbl) (3)   3.50       3.77       4.28       4.00  
    D&A per bbl ($/throughput bbl)   1.81       1.79       2.00       1.81  
                   
    Wyoming Refinery              
    Feedstocks throughput (Mbpd)   19.4       19.5       18.8       17.7  
                   
    Yield (% of total throughput)              
    Gasoline and gasoline blendstocks   43.7 %     46.7 %     45.7 %     46.0 %
    Distillate   49.0 %     47.1 %     48.1 %     47.3 %
    Fuel oils   3.4 %     2.5 %     2.5 %     2.5 %
    Other products   2.3 %     1.7 %     2.2 %     1.7 %
    Total yield   98.4 %     98.0 %     98.5 %     97.5 %
                   
    Refined product sales volume (Mbpd)   20.0       19.6       19.4       18.3  
                   
    Adjusted Gross Margin per bbl ($/throughput bbl) (2) $ 13.65     $ 37.01     $ 14.42     $ 28.88  
    Production costs per bbl ($/throughput bbl) (3)   7.00       6.46       7.30       7.34  
    D&A per bbl ($/throughput bbl)   2.43       2.41       2.51       2.69  
                   
    Market Indices ($ per barrel)              
    3-1-2 Singapore Crack Spread (4) $ 11.00     $ 23.39     $ 14.04     $ 19.45  
    RVO Adj. Pacific Northwest 3-1-1-1 Index (5)   15.48       35.00       19.49       28.51  
    RVO Adj. USGC 3-2-1 Index (6)   14.14       29.65       17.79       25.96  
                   
    Crude Oil Prices ($ per barrel)              
    Brent $ 78.71     $ 85.92     $ 81.82     $ 81.93  
    WTI   75.27       82.22       77.61       77.28  
    ANS (7)   80.26       89.25       83.49       82.57  
    Bakken Clearbrook   74.41       83.58       76.22       79.38  
    WCS Hardisty   59.98       65.42       62.20       60.75  
    Brent M1-M3   1.31       1.27       1.22       0.74  
                   
    Retail Segment              
    Retail sales volumes (thousands of gallons)   31,232       31,137       91,186       87,710  

    ______________________________
    (1)   Feedstocks throughput and sales volumes per day for the Montana refinery for the three and nine months ended September 30, 2023 are calculated based on the 92 and 122-day periods for which we owned the Montana refinery during the three and nine months ended September 30, 2023, respectively. As such, the amounts for the total refining segment represent the sum of the Hawaii, Washington, and Wyoming refineries’ throughput or sales volumes averaged over the three and nine months ended September 30, 2023, plus the Montana refinery’s throughput or sales volumes averaged over the periods from July 1, 2023 to September 30, 2023 and June 1, 2023 to September 30, 2023, respectively. The 2024 amounts for the total refining segment represent the sum of the Hawaii, Montana, Washington, and Wyoming refineries’ throughput or sales volumes averaged over the three and nine months ended September 30, 2024.
    (2)   We calculate Adjusted Gross Margin per barrel by dividing Adjusted Gross Margin by total refining throughput. Adjusted Gross Margin for our Washington refinery is determined under the last-in, first-out (“LIFO”) inventory costing method. Adjusted Gross Margin for our other refineries is determined under the first-in, first-out (“FIFO”) inventory costing method.
    (3)   Management uses production costs per barrel to evaluate performance and compare efficiency to other companies in the industry. There are a variety of ways to calculate production costs per barrel; different companies within the industry calculate it in different ways. We calculate production costs per barrel by dividing all direct production costs, which include the costs to run the refineries including personnel costs, repair and maintenance costs, insurance, utilities, and other miscellaneous costs, by total refining throughput. Our production costs are included in Operating expense (excluding depreciation) on our condensed consolidated statements of operations, which also includes costs related to our bulk marketing operations and severance costs.
    (4)   We believe the 3-1-2 Singapore Crack Spread (or three barrels of Brent crude oil converted into one barrel of gasoline and two barrels of distillates (diesel and jet fuel)) is the most representative market indicator for our operations in Hawaii.
    (5)   We believe the RVO Adjusted Pacific Northwest 3-1-1-1 Index (or three barrels of WTI crude oil converted into one barrel of Pacific Northwest gasoline, one barrel of Pacific Northwest ULSD and one barrel of USGC VGO, less 100% of the RVO cost for gasoline and ULSD) is the most representative market indicator for our operations in Washington.
    (6)   We believe the RVO Adjusted USGC 3-2-1 Index (or three barrels of WTI crude oil converted into two barrels of USGC gasoline and one barrel of USGC ULSD, less 100% of the RVO cost) is the most representative market indicator for our operations in Montana and Wyoming.
    (7)   ANS crude price influences the Hawaii Refinery’s financial performance. Beginning in September 2024, the ANS index has been updated from a Platts marker to an Argus marker to better reflect the prompt ANS market.


    Non-GAAP Performance Measures

    Management uses certain financial measures to evaluate our operating performance that are considered non-GAAP financial measures. These measures should not be considered in isolation or as substitutes or alternatives to their most directly comparable GAAP financial measures or any other measure of financial performance or liquidity presented in accordance with GAAP. These non-GAAP measures may not be comparable to similarly titled measures used by other companies since each company may define these terms differently.

    We believe Adjusted Gross Margin (as defined below) provides useful information to investors because it eliminates the gross impact of volatile commodity prices and adjusts for certain non-cash items and timing differences created by our inventory financing agreements and lower of cost and net realizable value adjustments to demonstrate the earnings potential of the business before other fixed and variable costs, which are reported separately in Operating expense (excluding depreciation) and Depreciation and amortization. Management uses Adjusted Gross Margin per barrel to evaluate operating performance and compare profitability to other companies in the industry and to industry benchmarks. We believe Adjusted Net Income (Loss) and Adjusted EBITDA (as defined below) are useful supplemental financial measures that allow investors to assess the financial performance of our assets without regard to financing methods, capital structure, or historical cost basis, the ability of our assets to generate cash to pay interest on our indebtedness, and our operating performance and return on invested capital as compared to other companies without regard to financing methods and capital structure. We believe Adjusted EBITDA by segment (as defined below) is a useful supplemental financial measure to evaluate the economic performance of our segments without regard to financing methods, capital structure, or historical cost basis.

    Beginning with financial results reported for the second quarter of 2023, Adjusted Gross Margin, Adjusted Net Income (Loss), and Adjusted EBITDA also exclude our portion of interest, taxes, and depreciation expense from our refining and logistics investments acquired on June 1, 2023, as part of the Billings Acquisition.

    Beginning with financial results reported for the fourth quarter of 2023, Adjusted Gross Margin, Adjusted Net Income (Loss), and Adjusted EBITDA excludes all hedge losses (gains) associated with our Washington ending inventory and LIFO layer increment impacts associated with our Washington inventory. In addition, we have modified our environmental obligation mark-to-market adjustment to include only the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington Climate Commitment Act (“Washington CCA”) and Clean Fuel Standard. This modification was made as part of our change in how we estimate our environmental obligation liabilities.

    Beginning with financial results reported for the fourth quarter of 2023, Adjusted Net Income (loss) excludes unrealized interest rate derivative losses (gains) and all Laramie Energy related impacts with the exception of cash distributions. We have recast Adjusted Net Income (Loss) for prior periods when reported to conform to the modified presentation.

    Beginning with financial results reported for the first quarter of 2024, Adjusted Net Income (loss) also excludes other non-operating income and expenses. This modification improves comparability between periods by excluding income and expenses resulting from non-operating activities.

    Adjusted Gross Margin

    Adjusted Gross Margin is defined as operating income (loss) excluding:

      operating expense (excluding depreciation);
      depreciation and amortization (“D&A”);
      Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments;
      impairment expense;
      loss (gain) on sale of assets, net;
      inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
      Environmental obligation mark-to-market adjustments (which represents the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington CCA and Clean Fuel Standard); and
      unrealized loss (gain) on derivatives.

    The following tables present a reconciliation of Adjusted Gross Margin to the most directly comparable GAAP financial measure, operating income (loss), on a historical basis, for selected segments, for the periods indicated (in thousands):

    Three months ended September 30, 2024 Refining   Logistics   Retail
    Operating income $ 19,005     $ 26,164   $ 18,274
    Operating expense (excluding depreciation)   122,054       3,334     21,661
    Depreciation and amortization   22,623       5,925     2,680
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   658       861    
    Inventory valuation adjustment   14,057          
    Environmental obligation mark-to-market adjustments   (4,432 )        
    Unrealized gain on commodity derivatives   (31,772 )        
    Gain on sale of assets, net            
    Adjusted Gross Margin (1) $ 142,193     $ 36,284   $ 42,615
    Three months ended September 30, 2023 Refining   Logistics   Retail
    Operating income $ 194,847     $ 20,736   $ 13,315
    Operating expense (excluding depreciation)   116,949       6,135     22,099
    Depreciation and amortization   24,278       7,708     2,766
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   821       698    
    Inventory valuation adjustment   72,823          
    Environmental obligation mark-to-market adjustments   (50,153 )        
    Unrealized gain on commodity derivatives   (8,995 )        
    Adjusted Gross Margin (1) $ 350,570     $ 35,277   $ 38,180
    Nine Months Ended September 30, 2024 Refining   Logistics   Retail
    Operating income $ 82,811     $ 64,579   $ 45,323  
    Operating expense (excluding depreciation)   365,031       11,847     67,511  
    Depreciation and amortization   66,584       19,893     8,471  
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   2,037       2,550      
    Inventory valuation adjustment   (6,419 )          
    Environmental obligation mark-to-market adjustments   (18,199 )          
    Unrealized loss on commodity derivatives   34,061            
    Loss (gain) on sale of assets, net         124     (10 )
    Adjusted Gross Margin (1) $ 525,906     $ 98,993   $ 121,295  
    Nine Months Ended September 30, 2023 Refining   Logistics   Retail
    Operating income $ 502,123     $ 54,035   $ 42,009
    Operating expense (excluding depreciation)   252,802       13,178     64,166
    Depreciation and amortization   59,827       17,801     8,577
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   821       905    
    Inventory valuation adjustment   126,799          
    Environmental obligation mark-to-market adjustments   (174,111 )        
    Unrealized gain on commodity derivatives   (487 )        
    Adjusted Gross Margin (1) $ 767,774     $ 85,919   $ 114,752

    ______________________________
    (1)   For the three and nine months ended September 30, 2024 and 2023, there was no impairment expense in Operating income. For the three months ended September 30, 2024 and the three and nine months ended September 30, 2023, there was no (gain) loss on sale of assets recorded in Operating income.


    Adjusted Net Income (Loss) and Adjusted EBITDA

    Adjusted Net Income (Loss) is defined as Net income (loss) excluding:

      inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
      Environmental obligation mark-to-market adjustments (which represents the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington CCA and Clean Fuel Standard);
      unrealized (gain) loss on derivatives;
      acquisition and integration costs;
      redevelopment and other costs related to Par West;
      debt extinguishment and commitment costs;
      increase in (release of) tax valuation allowance and other deferred tax items;
      changes in the value of contingent consideration and common stock warrants;
      severance costs and other non-operating expense (income);
      (gain) loss on sale of assets;
      impairment expense;
      impairment expense associated with our investment in Laramie Energy; and
      Par’s share of equity (earnings) losses from Laramie Energy, LLC, excluding cash distributions.

    Adjusted EBITDA is defined as Adjusted Net Income (Loss) excluding:

      D&A;
      interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain);
      cash distributions from Laramie Energy, LLC to Par;
      Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments; and
      income tax expense (benefit) excluding the increase in (release of) tax valuation allowance.

    The following table presents a reconciliation of Adjusted Net Income (Loss) and Adjusted EBITDA to the most directly comparable GAAP financial measure, net income (loss), on a historical basis for the periods indicated (in thousands):        

      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Net income $ 7,486     $ 171,415     $ 22,373     $ 439,318  
    Inventory valuation adjustment   14,057       72,823       (6,419 )     126,799  
    Environmental obligation mark-to-market adjustments   (4,432 )     (50,153 )     (18,199 )     (174,111 )
    Unrealized loss (gain) on derivatives   (31,196 )     (9,116 )     33,756       (1,151 )
    Acquisition and integration costs   (23 )     4,669       68       17,213  
    Par West redevelopment and other costs   4,006       3,127       9,048       8,490  
    Debt extinguishment and commitment costs               1,418       17,682  
    Changes in valuation allowance and other deferred tax items (1)   5,707             9,238        
    Severance costs and other non-operating expense (2)   (1,490 )     615       14,648       1,685  
    Loss on sale of assets, net               114        
    Equity (earnings) losses from Laramie Energy, LLC, excluding cash distributions   336             (1,382 )      
    Adjusted Net Income (Loss) (3)   (5,549 )     193,380       64,663       435,925  
    Depreciation and amortization   31,879       35,311       96,679       87,887  
    Interest expense and financing costs, net, excluding unrealized interest rate derivative loss (gain)   22,826       20,936       62,025       52,638  
    Laramie Energy, LLC cash distributions to Par               (1,485 )     (10,706 )
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   1,519       1,519       4,587       1,726  
    Income tax expense (benefit)   753       4,600       1,258       6,741  
    Adjusted EBITDA (3) $ 51,428     $ 255,746     $ 227,727     $ 574,211  

    ______________________________
    (1)   For the three and nine months ended September 30, 2024, we recognized a non-cash deferred tax expense of $5.7 million and $9.2 million, respectively, related to deferred state and federal tax liabilities. This tax benefit is included in Income tax expense (benefit) on our consolidated statements of operations. For the three and nine months ended September 30, 2023, we did not have any adjustments to our valuation allowance and other deferred tax items.
    (2)   For the nine months ended September 30, 2024, we incurred $13.1 million of stock-based compensation expenses associated with accelerated vesting of equity awards and modification of vested equity awards related to our CEO transition and $2.3 million for an estimated legal settlement unrelated to current operating activities.
    (3)   For the three and nine months ended September 30, 2024 and 2023, there was no change in value of contingent consideration, change in value of common stock warrants, impairment expense, impairments associated with our investment in Laramie Energy, or our share of Laramie Energy’s asset impairment losses in excess of our basis difference. Please read the Non-GAAP Performance Measures discussion above for information regarding changes to the components of Adjusted Net Income (Loss) and Adjusted EBITDA made during the reporting periods.

    The following table sets forth the computation of basic and diluted Adjusted Net Income (Loss) per share (in thousands, except per share amounts):

      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023     2024     2023
    Adjusted Net Income (Loss) $ (5,549 )   $ 193,380   $ 64,663   $ 435,925
    Plus: effect of convertible securities                
    Numerator for diluted income (loss) per common share $ (5,549 )   $ 193,380   $ 64,663   $ 435,925
                   
    Basic weighted-average common stock shares outstanding   55,729       60,223     57,283     60,241
    Add dilutive effects of common stock equivalents (1)         1,181     787     903
    Diluted weighted-average common stock shares outstanding   55,729       61,404     58,070     61,144
                   
    Basic Adjusted Net Income (Loss) per common share $ (0.10 )   $ 3.21   $ 1.13   $ 7.24
    Diluted Adjusted Net Income (Loss) per common share $ (0.10 )   $ 3.15   $ 1.11   $ 7.13

    ______________________________
    (1)   Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. We have utilized the basic shares outstanding to calculate both basic and diluted Adjusted Net Loss per common share for the three months ended September 30, 2024.


    Adjusted EBITDA by Segment

    Adjusted EBITDA by segment is defined as Operating income (loss) excluding:

      D&A;
      inventory valuation adjustment (which adjusts for timing differences to reflect the economics of our inventory financing agreements, including lower of cost or net realizable value adjustments, the impact of the embedded derivative repurchase or terminal obligations, hedge losses (gains) associated with our Washington ending inventory and intermediation obligation, purchase price allocation adjustments, and LIFO layer increment and decrement impacts associated with our Washington inventory);
      Environmental obligation mark-to-market adjustments (which represents the mark-to-market losses (gains) associated with our net RINs liability and net obligation associated with the Washington CCA and Clean Fuel Standard);
      unrealized (gain) loss on derivatives;
      acquisition and integration costs;
      redevelopment and other costs related to Par West;
      severance costs and other non-operating expense (income);
      (gain) loss on sale of assets;
      impairment expense; and
      Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments.

    Adjusted EBITDA by segment also includes Gain on curtailment of pension obligation and Other income (loss), net, which are presented below operating income (loss) on our condensed consolidated statements of operations.

    The following table presents a reconciliation of Adjusted EBITDA by segment to the most directly comparable GAAP financial measure, operating income (loss) by segment, on a historical basis, for selected segments, for the periods indicated (in thousands):

      Three Months Ended September 30, 2024
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $ 19,005     $ 26,164   $ 18,274   $ (27,012 )
    Depreciation and amortization   22,623       5,925     2,680     651  
    Inventory valuation adjustment   14,057                
    Environmental obligation mark-to-market adjustments   (4,432 )              
    Unrealized gain on commodity derivatives   (31,772 )              
    Acquisition and integration costs                 (23 )
    Par West redevelopment and other costs                 4,006  
    Severance costs and other non-operating expense                 (1,490 )
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   658       861          
    Other income, net                 1,253  
    Adjusted EBITDA (1) $ 20,139     $ 32,950   $ 20,954   $ (22,615 )
      Three Months Ended September 30, 2023
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $ 194,847     $ 20,736   $ 13,315   $ (32,025 )
    Depreciation and amortization   24,278       7,708     2,766     559  
    Inventory valuation adjustment   72,823                
    Environmental obligation mark-to-market adjustments   (50,153 )              
    Unrealized gain on commodity derivatives   (8,995 )              
    Acquisition and integration costs                 4,669  
    Par West redevelopment and other costs                 3,127  
    Severance costs and other non-operating expenses             580     35  
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   821       698          
    Other loss, net                 (43 )
    Adjusted EBITDA (1) $ 233,621     $ 29,142   $ 16,661   $ (23,678 )
      Nine Months Ended September 30, 2024
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $ 82,811     $ 64,579   $ 45,323     $ (98,126 )
    Depreciation and amortization   66,584       19,893     8,471       1,731  
    Inventory valuation adjustment   (6,419 )                
    Environmental obligation mark-to-market adjustments   (18,199 )                
    Unrealized loss on commodity derivatives   34,061                  
    Acquisition and integration costs                   68  
    Severance costs and other non-operating expenses   642                 14,006  
    Par West redevelopment and other costs                   9,048  
    Loss (gain) on sale of assets, net         124     (10 )      
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   2,037       2,550            
    Other loss, net                   (1,447 )
    Adjusted EBITDA (1) $ 161,517     $ 87,146   $ 53,784     $ (74,720 )
      Nine Months Ended September 30, 2023
      Refining   Logistics   Retail   Corporate and Other
    Operating income (loss) by segment $ 502,123     $ 54,035   $ 42,009   $ (93,459 )
    Depreciation and amortization   59,827       17,801     8,577     1,682  
    Inventory valuation adjustment   126,799                
    Environmental obligation mark-to-market adjustments   (174,111 )              
    Unrealized gain on commodity derivatives   (487 )              
    Acquisition and integration costs                 17,213  
    Severance costs and other non-operating expenses             580     1,105  
    Par West redevelopment and other costs                 8,490  
    Par’s portion of interest, taxes, and depreciation expense from refining and logistics investments   821       905          
    Other income, net                 301  
    Adjusted EBITDA (1) $ 514,972     $ 72,741   $ 51,166   $ (64,668 )

    ________________________________________
    (1)   For the three and nine months ended September 30, 2024 and 2023, there was no change in value of contingent consideration, change in value of common stock warrants, impairment expense, or impairments associated with our investment in Laramie Energy. For three months ended September 30, 2024 and for the three and nine months ended September 30, 2023, there was no loss (gain) on sale of assets.


    Laramie Energy Adjusted EBITDAX

    Adjusted EBITDAX is defined as net income (loss) excluding commodity derivative loss (gain), loss (gain) on settled derivative instruments, interest expense, gain on extinguishment of debt, non-cash preferred dividend, depreciation, depletion, amortization, and accretion, exploration and geological and geographical expense, bonus accrual, equity-based compensation expense, loss (gain) on disposal of assets, phantom units, and expired acreage (non-cash). We believe Adjusted EBITDAX is a useful supplemental financial measure to evaluate the economic and operational performance of exploration and production companies such as Laramie Energy.

    The following table presents a reconciliation of Laramie Energy’s Adjusted EBITDAX to the most directly comparable GAAP financial measure, net income (loss) for the periods indicated (in thousands):

      Three Months Ended September 30,   Nine Months Ended September 30,
        2024       2023       2024       2023  
    Net income (loss) $ (4,239 )   $ (3,479 )   $ (4,296 )   $ 54,048  
    Commodity derivative (income) loss   (5,234 )     1,889       (15,821 )     (32,951 )
    Gain (loss) on settled derivative instruments   5,584       2,775       14,220       (1,433 )
    Interest expense and loan fees   5,745       5,783       15,783       14,742  
    Gain on extinguishment of debt         (3,454 )           6,644  
    Non-cash preferred dividend                     2,910  
    Depreciation, depletion, amortization, and accretion   8,128       9,248       24,683       22,465  
    Phantom units   (217 )     2,425       (503 )     3,171  
    Loss (gain) on sale of assets, net   (8 )     239       (8 )     307  
    Expired acreage (non-cash)   157             722       112  
    Total Adjusted EBITDAX (1) $ 9,916     $ 15,426     $ 34,780     $ 70,015  

    ______________________________
    (1)   For the three and nine months ended September 30, 2024 and 2023, there was no exploration and geological and geographical expense, bonus accrual, or equity-based compensation expense.

    The MIL Network

  • MIL-OSI United Nations: Leadership for Peace Means ‘Living Up to UN Charter’, Says Secretary-General at Security Council Debate

    Source: United Nations – Peacekeeping

    Following are UN Secretary-General António Guterres’ remarks to the Security Council’s high-level debate on “Leadership for peace:  united in respect of the UN Charter, in search of a secure future”, in New York today:

    I thank the Government of Slovenia for convening this high-level debate on Leadership for Peace.

    The topic is rooted in a fundamental truth:  Peace is never automatic.  Peace demands action.  And peace demands leadership.

    Instead, we’re seeing deepening geo-political divisions and mistrust.  Impunity is spreading, with repeated violations of international law and the UN Charter.   Conflicts are multiplying, becoming more complex and deadlier. All regions are affected.

    And civilians are paying the steepest price.  From Gaza to Ukraine to Sudan and beyond — wars grind on, suffering grows, hunger deepens, lives are upended, and the legitimacy and effectiveness of the United Nations, and this Council, are undermined.

    Leadership for peace requires action in at least two key areas.

    First — leadership for peace means all Member States living up to their commitments in the UN Charter, in international law and in recent agreements such as the Pact for the Future.

    Among other things, the Pact calls for strengthening tools and frameworks to prevent conflict, sustain peace and advance sustainable development, with the full, equal and meaningful participation of women.

    It calls for updating our tools for peace operations to allow for more agile, tailored responses to existing, emerging and future challenges.

    It reinforces the commitment to all human rights — civil, political, economic, social and cultural.

    It includes initiatives around disarmament, peacebuilding, and managing threats posed by lethal autonomous weapons and artificial intelligence and in new domains, including outer space and cyberspace.

    It calls for measures to quickly address complex global shocks. And it contains a new push to reform key institutions of global governance, including the global financial architecture and this very Council.

    The Pact is a down-payment on these reforms.  But we will need strong political will to implement them and rebuild the legitimacy and effectiveness of this Council.  Which brings me to my second point about leadership for peace.

    Leadership for peace means ensuring that the UN Security Council acts in a meaningful way to ease global tensions and help address the conflicts that are inflicting so much suffering around the world.

    Geopolitical divisions continue to block effective solutions.  A united Council can make a tremendous difference for peace.  A divided Council cannot.  It is imperative that Council Members spare no effort to work together to find common ground.  And it has proven capable of doing so in some key areas.

    From currently overseeing 11 peacekeeping operations on three continents, involving nearly 70,000 uniformed peacekeeping personnel…

    To resolutions that help keep vital humanitarian aid flowing to the world’s hotspots…

    To the landmark resolution 2719 (2023), which provides for African-Union led peace support operations authorized by the Council to have access to UN assessed contributions…

    To the groundbreaking resolutions that recognized the clear implications of peace and security challenges on the lives of women and youth…

    To this Council’s growing ties to regional and subregional organizations to foster consensus and peace.  These examples — and more — prove that forging peace is possible.

    When we consider the most difficult and intractable conflicts on this Council’s agenda, peace can seem an impossible dream.

    But I strongly believe that peace is possible if we stick to principles.  Peace in Ukraine is possible.  By following the UN Charter and abiding by international law.

    Peace in Gaza is possible.  By sparing no effort for an immediate ceasefire, the immediate release of all hostages, and the beginning of an irreversible process towards a two-State solution.

    Peace in Sudan is possible.  By sending a clear message to the warring parties that all Members of this Council — including the five permanent Members — will not tolerate the horrific violence and desperate humanitarian crisis being unleashed on innocent civilians.

    The situations on this Council’s agenda are complex and do not have quick fixes.  But the scale of the challenge should not deter us.  Our only hope for progress on peace is active collaboration and unity among Council Members.

    Today, I call on all Members to live up to this great responsibility, and to the promise of the UN Charter.  Contribute to this Council’s success — not its diminishment.  Let’s ensure that this Council serves as an effective and representative forum for peace — today and in the years to come.

    MIL OSI United Nations News

  • MIL-OSI Video: Occupied Palestinian Territory, Ukraine, Lebanon & other topics – Daily Press Briefing (4 Nov 2024)

    Source: United Nations (Video News)

    Noon Briefing by Stéphane Dujarric, Spokesperson for the Secretary-General.

    Highlights:
    -Occupied Palestinian Territory
    -Lebanon/Israel
    -Lebanon/Humanitarian
    -Ukraine
    -Ukraine/Humanitarian
    -Security Council
    -Rosemary DiCarlo/Japan
    -West and Central Africa
    -Democratic Republic of the Congo
    -Deputy Secretary-General
    -World Urban Forum
    -Counter-Terrorism
    -Resident Coordinator – Honduras
    -NY marathon
    -Briefings today

    Occupied Palestinian Territory
    In Gaza, the Office for the Coordination of Humanitarian Affairs is deeply concerned about persistent reports of mounting casualties, with the number of Palestinians being killed and injured especially high in North Gaza Governorate, where the Israeli military operations are continuing.
    In a statement on Saturday, Catherine Russell, the UNICEF, Children’s Fund head, said that more than 50 children had reportedly been killed in Jabalya over the previous two days alone, after strikes leveled two residential buildings sheltering hundreds of people.
    Meanwhile, our humanitarian colleagues tell us that, for the past month, Israeli authorities have only allowed humanitarian access to Jabalya, Beit Lahia and Beit Hanoun on an exceptional basis, leaving us unable to confirm the conditions of people inside and we worry for their safety.
    OCHA warns that the already limited humanitarian supplies entering Gaza have dwindled even further since October. Private imports are virtually banned, and Israeli authorities are only allowing the use of three entry points – Kerem Shalom, Gate 96, which is near Deir Al-Balah and Erez West. Furthermore, humanitarian colleagues can only access these border areas by highly dangerous routes. The use of most roads leading to these entry points has either been banned by the Israeli authorities or rendered unsafe due to the ongoing hostilities.
    The routes available are often in poor condition and prone to armed looting fueled by the breakdown in public order and safety.
    Our humanitarian colleagues note that supplies reaching the northern crossing at Erez West can only be sent to Gaza city, as requests to deliver them to besieged areas in North Gaza governorate are being consistently denied and rejected.
    For its part, the World Food Programme warns that as winter approaches, the lack of food and other vital humanitarian supplies entering the Gaza Strip could soon escalate into famine unless immediate action is taken. In October, the World Food Programme has only been able to reach 42 per cent of the 1.1 million people targeted for food assistance in Gaza, with reduced rations due to dropping aid levels.

    Lebanon/Israel
    An update from UNIFIL, who is noting with continued concern the airstrikes by the Israel Defense Forces across Lebanon over the weekend, including in the South, in Sidon, Baalbek and Beirut, resulting in several casualties. In southern Lebanon, the peacekeepers report that IDF operations have continued, involving clashes with Hizbullah. Meanwhile, they also report that Hizbullah has continued to launch drones and dozens of rockets South, into Israel.
    The increasing impact on civilians is of grave concern and we condemn the loss of civilian lives. All actors must adhere to international law and protect civilians and civilian infrastructure. UNIFIL premises also continue to be impacted. On 2 November, a UN position near Markaba, in Sector East, sustained damage to its prefabricated containers and perimeters caused by demolition operations being undertaken by the IDF.
    A nearby explosion also damaged a UN vehicle at the [UNIFIL] Naqoura Headquarters, with no injuries reported. We once again remind all actors of the inviolability of the UN premises and their responsibility to protect UN peacekeepers.
    We urge the parties to halt the violence immediately. The United Nations continues to support efforts towards a ceasefire and a diplomatic solution.

    Full Highlights: https://www.un.org/sg/en/content/noon-briefing-highlight?date%5Bvalue%5D%5Bdate%5D=04%20November%202024

    https://www.youtube.com/watch?v=YHC60gr1Lo8

    MIL OSI Video

  • MIL-OSI Security: NATO Secretary General in Berlin: “your support saves lives on the battlefield every day”

    Source: NATO

    During his first official visit to Berlin on Monday (4 November), NATO Secretary General Mark Rutte thanked Chancellor Olaf Scholz for Germany’s significant contributions to the Alliance and its ongoing support for Ukraine.

    The Secretary General praised Chancellor Scholz’s “personal leadership and commitment” to investing more in defence. “Germany now invests 2 percent of its GDP in defence for the first time in three decades. This is important for Germany and for NATO,” he said.
     
    The Secretary General highlighted Germany’s contributions to NATO, including its presence in the eastern part of the Alliance where it is stationing a full brigade in Lithuania. Mr Rutte welcomed the opening of Germany’s new naval headquarters in Rostock, which will help to protect key trade and supply routes, and critical infrastructure in the Baltic Sea.
     
    Mr Rutte also thanked Germany for being “the biggest European contributor of military aid” to Ukraine, underlining that Germany’s support “saves lives on the battlefield every day.” He also warned of more frequent Russian hybrid attacks against NATO Allies, saying “the shifting frontline in this war is no longer solely within Ukraine.”  Russia is interfering directly in Allies’ democracies, sabotaging industry and committing violence. “All of this to weaken us and to sow divisions, but NATO stands ready to deter and defend against these threats,” he said.
     
    On Monday, the Secretary General also met with German President Frank-Walter Steinmeier, Minister of Defence Boris Pistorius, and Chairman of the Defence Committee of the German Bundestag Marcus Faber.

    MIL Security OSI

  • MIL-OSI United Nations: Human Rights Committee Adopts Report on Views Concerning Individual Communications on Colombia, Ecuador, Finland, Greece, New Zealand, Sweden, Türkiye, Turkmenistan and Ukraine

    Source: United Nations – Geneva

    The Human Rights Committee today adopted a follow-up progress report on individual communications, presented by the Special Rapporteur for follow-up on Views, which concerned communications on Colombia, Ecuador, Finland, Greece, New Zealand, Sweden, Türkiye, Turkmenistan and Ukraine.

    José Manuel Santos Pais, Special Rapporteur for follow-up on Views, said one individual communication on Colombia concerned a case of enforced disappearance by parliamentary groups.  The State party was urged to conduct an independent, thorough and effective investigation of the disappearances of Mr. Anzola and Mr. Molina and prosecute and punish those responsible; release these people if they were still alive; if they were dead, hand-over their remains to their family; and ensure effective reparation, including adequate compensation, and medical and psychological rehabilitation for the authors for the violations suffered. The State party was also under an obligation to prevent similar violations from occurring in the future and to ensure that any forced disappearances gave rise to prompt, impartial and effective investigations.  The State party had established a search and investigative unit, but one Committee member noted that many measures had not been implemented and there seemed to be no urgency.  The Committee recommended ongoing follow-up dialogue.

    A second communication on Colombia involved the killing of a trade unionist.  The Committee recommended that the State party promptly conduct a thorough, effective, impartial, independent and transparent investigation into the circumstances surrounding the murder, to establish the truth; provide the family members who were the authors with detailed information about the results of the investigation; and provide adequate compensation to the family members, including sufficient compensation to cover the reasonable legal expenses they have incurred. The State party had reported that it would proceed with the compensation procedure and had published the Committee’s Views publicly.  However, it was reported that the State party had not conducted the criminal investigation in a way conducive to the identification of the perpetrators or to shed light on the reasons behind the murder.  The Committee therefore recommended follow-up dialogue. 

    Regarding Ecuador, the communication concerned criminal conviction and the seizure of assets. The Committee recommended making full reparation to the persons whose rights had been violated and ensuring that due process was followed in the relevant suits at law.  The State party had outlined that the Committee had not recommended restitution but called for ensuring effective remedy.  It was acknowledged that partial reparation had been granted by the courts, with an appeal still pending.  There were several conflicting interests in regards to this case.  The Committee decided to close the case with partial satisfaction of the Committee’s Views, because the Views issued did not address directly the return of assets to the author, but gave them the possibility to contest the decisions, which had occurred. 

    On Finland, the communication related to the right to vote for elections at the Sami Parliament. The Committee had requested effective remedy, including to make full reparation to individuals whose rights had been violated.  The State party was obligated to review the Act on the Sami Parliament with a view to ensuring that the criteria for eligibility to vote in Sami Parliament elections was defined and applied in a manner that respected the right of the Sami people to exercise their internal self-determination.  A detailed proposal sent to the State party had requested several measures, but the authors had not received any written responses to their proposals.  The Committee recommended ongoing follow-up dialogue. 

    The communication for Greece concerned conscientious objection to compulsory military service.  Remedies proposed by the Committee included expunging the author’s criminal record, reimbursing all sums paid as fines, providing him with adequate compensation, taking all steps necessary to prevent similar violations in the future, and reviewing the legislation with a view to ensuring the effective guarantee of the right to conscientious objection.  The Committee noted there were some positive steps taken, however, some human rights violations remained unaddressed. Contentious objectors still faced discrimination, and in some cases punishment, including fines and imprisonment.  The State was requested to continue follow-up dialogue and was encouraged to look further into the matter. 

    On New Zealand, the communication concerned compensation for wrongful arrest and detention. The Committee recommended providing the author with adequate compensation and taking all steps to prevent similar violations from occurring in the future, including by reviewing its domestic legislation, to ensure that individuals who had been unlawfully arrested or detained as a result of judicial acts could apply to receive adequate compensations.  The State party had requested a consultation process with civil society, but there was no timeline provided and no deadline for the subsequent report to be submitted to the Committee.  The absence of legislative action demonstrated a lack of willingness on behalf of the State party to fulfil its obligations.  In this regard, the Committee recommended follow-up dialogue and would request a meeting with a representative of the State party during a future session. 

    Regarding Sweden, the communication concerned deportation to Albania.  The Committee had recommended that Sweden review the authors’ claims, taking into account the State party’s obligations under the Covenant and the Committee’s present Views, and refrain from expelling the authors to Albania while their requests for asylum were under reconsideration.  The State party heeded to the Committee’s recommendations and therefore the Committee decided to close the follow-up dialogue with a note of satisfactory implementation of the Committee’s Views. 

    In the individual communication on Türkiye, which concerned conscientious objection to military service by Jehovah’s Witnesses, the Committee recommended expunging their criminal records, providing them with adequate compensation, and avoiding similar violations of the Covenant in the future.  The State party submitted that it had made amendments regarding crimes related to compulsory military services, and had also abolished the military courts, which the Committee described as a welcome development.  However, the author reported that their criminal records had not been expunged, they had not been provided with compensation, and they were still subject to military conscription.  Given this, the Committee recommended follow-up dialogue. 

    On Turkmenistan, the communication included conscientious objection to compulsory military service.  The Committee’s recommendations included expunging the author’s criminal record, providing them with adequate compensation, including by reimbursing any legal costs, and taking steps to prevent similar violations from occurring in the future, including by reviewing the legislation of the State party, for instance by providing for the possibility of alternative service of a civilian nature. The author’s counsel had stated that neither he nor the author were aware of any steps taken by the State party to implement the Committee’s Views.  One Expert noted there was no convincing evidence that the State party had contemplated compensation of any kind to the author.  The Committee decided to close the follow-up dialogue with a note of unsatisfactory implementation of the Committee’s recommendation. 

    On Ukraine, the communication concerned the impossibility of having life sentence reviewed. The Committee recommended providing the author with a meaningful review of his sentence of life imprisonment on the basis of a clear and predictable procedure, providing him with adequate compensation, and taking all steps necessary to prevent similar violations in the future.  Due to the escalating conflict in Ukraine, the author requested that his life imprisonment be replaced with a fixed term imprisonment, which did not exceed 15 years of imprisonment, however, this was rejected by the Supreme Court.  In this regard, the Committee recommended follow-up dialogue, but noted positively, that the State party had prepared legislation allowing for any convicted person to have their life sentence considered by the court. 

    In closing remarks, Mr. Santos Pais said it was his last report as Rapporteur on follow-up to Views.  The report on follow-up to Views was essential in monitoring the Committee’s Views and ensuring victims had access to effective remedies.  It also ensured accountability for States under the Optional Protocol.  He thanked all those who had contributed to the report which was very much a team effort. 

    The Human Rights Committee’s one hundred and forty-second session is being held from 14 October to 7 November 2024.  All the documents relating to the Committee’s work, including reports submitted by States parties, can be found on the session’s webpage.  Meeting summary releases can be found here.  The webcast of the Committee’s public meetings can be accessed via the UN Web TV webpage.

    The Committee will next meet in public at 3 p.m. on Thursday, 7 November to close its one hundred and forty-second session.

     

    Produced by the United Nations Information Service in Geneva for use of the media; 
    not an official record. English and French versions of our releases are different as they are the product of two separate coverage teams that work independently.

     

    CCPR24.024E

    MIL OSI United Nations News

  • MIL-OSI USA: Virginia Company and Two Senior Executives Charged with Illegally Exporting Millions of Dollars of U.S. Technology to Russia

    Source: US State Government of Utah

    Eleview International Inc., Oleg Nayandin, 54, of Fairfax, Virginia, and Vitaliy Borisenko, 39, of Vienna, Virginia, made their initial appearance today in the Eastern District of Virginia pursuant to a now unsealed complaint charging them with conspiracy to violate the Export Control Reform Act.

    “As alleged, the defendants — a Virginia company and two of its senior executives — conspired through three evasion schemes to circumvent the export restrictions imposed on Russia following its invasion of Ukraine,” said Assistant Attorney General Matthew G. Olsen of the Justice Department’s National Security Division. “U.S. companies are responsible for complying with laws that protect our national security. The National Security Division is committed to holding accountable individuals and companies who violate these laws and place financial profit over our collective security.”

    “This company allegedly used not one, not two, but three different schemes to illegally transship sensitive American technology to Russia,” said Assistant Secretary for Export Enforcement Matthew S. Axelrod of the Department of Commerce, Bureau of Industry and Security (BIS). “Today’s charges, against both the company and two top executives, are a prime example of our work to bring to justice both the companies and the corporate executives alleged to have circumvented our rules in search of a fatter bottom line.”

    “We must not allow critical systems and technologies to be transferred to anyone who may use them against America and our global partners,” said U.S. Attorney Jessica D. Aber for the Eastern District of Virginia. “Guarding against these transfers is imperative, and violations of the laws that protect our national security will be met with ardent prosecution.”

    “Export control evasion schemes put the American public at risk by concealing the true recipient,” said Special Agent in Charge Derek W. Gordon of Homeland Security Investigations Washington, D.C. “In this instance, HSI, working in partnership with our colleagues at Department of Commerce’s Office of Export Enforcement, uncovered this scheme was supporting a sanctioned country, thus threatening our national security and the safety of other countries. HSI is dedicated to preventing technology with military applications from falling into the wrong hands.”

    According to the complaint, between approximately March 2022 and June 2023, Eleview International Inc. (Eleview), allegedly a Virginia-based company that operated a freight consolidation and forwarding business; Nayandin, the owner, president, and CEO of Eleview; and Borisenko, who oversaw the day-to-day operations of Eleview’s freight forwarding business, conspired to illegally export goods and technology from the United States to Russia by transshipping them through three countries bordering or near Russia.

    As alleged, the defendants operated an e-commerce website that allowed Russian customers to order U.S. goods and technology directly from U.S. retailers, who shipped the items to Eleview’s warehouse in Chantilly, Virginia. The defendants then consolidated the packages before shipping them to the Russian customers, often using other freight forwarders as intermediaries, in exchange for a fee. After the Department of Commerce imposed stricter export controls in response to Russia’s further invasion of Ukraine in February 2022, the defendants began shipping items to purported end users in Turkey, Finland, and Kazakhstan, knowing that the items were ultimately destined for end users in Russia. To facilitate these illegal exports, the defendants made numerous false statements to the Department of Commerce and other freight forwarders about the end users and ultimate consignees of the items in these shipments.

    As part of the conspiracy, the defendants engaged in three export-control evasion schemes, each specific to a different intermediary country. In the Turkey scheme, the defendants exported about $1.48 million worth of telecommunications equipment to a false end user in Turkey, knowing that the equipment was intended for a Russian telecommunications company that supplied the Russian government, including the Federal Security Service, or FSB. The telecommunications equipment that the defendants illegally exported as part of the Turkey scheme had military applications, including use by the Russian military to create and expand communication networks in its war effort against Ukraine.

    In the Finland scheme, the defendants exported about $3.45 million worth of goods purchased to Russia through Eleview’s e-commerce website to a false end user in Finland that neither purchased nor sold goods. Before consolidating the packages into larger pallets for shipment to Finland, the defendants affixed to each package a label with a Russian postal service tracking number so that the Russian postal service could easily ship the package to the customer in Russia. The goods that the defendants illegally exported as part of the Finland scheme included “high priority” items that the Department of Commerce has identified as particularly significant to Russian weaponry, including the same type of electronic component found on Russian “suicide” drones used to destroy Ukrainian tanks and jets.

    In the Kazakhstan scheme, the defendants exported about $1.47 million worth of goods to Russia through an entity in Kazakhstan that advertises its ability to deliver goods to Russia. The goods that the defendants illegally exported as part of the Kazakhstan scheme included controlled dual-use items.

    If convicted, Nayandin and Borisenko each face a maximum penalty of 20 years in prison. A federal district court judge will determine any sentence after considering the U.S. Sentencing Guidelines and other statutory factors.

    The BIS and Homeland Security Investigations are investigating the case.

    Assistant U.S. Attorneys Gavin R. Tisdale and Amanda St. Cyr for the Eastern District of Virginia and Trial Attorney Garrett Coyle of the National Security Division’s Counterintelligence and Export Control Section are prosecuting the case with past assistance provided by then-First Assistant U.S. Attorney Raj Parekh.

    The case is being coordinated through the Justice and Commerce Departments’ Disruptive Technology Strike Force and the Justice Department’s Task Force KleptoCapture. The Disruptive Technology Strike Force is an interagency law enforcement strike force co-led by the Justice and Commerce Departments designed to target illicit actors, protect supply chains, and prevent critical technology from being acquired by authoritarian regimes and hostile nation states. Task Force KleptoCapture is an interagency law enforcement task force dedicated to enforcing the sweeping sanctions, export restrictions and economic countermeasures that the United States has imposed, along with its allies and partners, in response to Russia’s unprovoked military invasion of Ukraine.

    A criminal complaint is merely an allegation. All defendants are presumed innocent until proven guilty beyond a reasonable doubt in a court of law.

    MIL OSI USA News

  • MIL-OSI USA: Pentagon Press Secretary Maj. Gen. Pat Ryder Holds Press Briefing

    Source: United States Department of Defense

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  All right. Good afternoon, everyone. Looks like there’s something wrong with this side of the room here since everybody’s on this side of the room, but OK. All right. Well, just a few things at the top and I’ll be glad to take your questions. So as many of you saw in the statement that we released on Friday, Secretary Austin ordered the deployment of additional ballistic missile defense destroyers, fighter squadrons, and tanker aircraft and several US Air Force B-52 long range strike bombers to the US Central Command area of responsibility.

    These forces will begin to arrive in the coming months as the USS Abraham Lincoln Carrier Strike Group prepares to depart, some of which have already begun to flow into theater as highlighted by the arrival of the B-52 bombers over the weekend. These deployments are in keeping with our commitments to the protection of US citizens and forces in the Middle East, the defense of Israel, and de-escalation through deterrence and diplomacy.

    These movements build on the recent decision to deploy the Terminal High Altitude Area Defense Missile Defense system to Israel, as well as DOD’s sustained Amphibious Ready Group / Marine Expeditionary Unit posture in the Eastern Mediterranean and demonstrate the flexible nature of US global defense posture and US capability to deploy worldwide on short notice to meet evolving national security threats.

    Secretary Austin continues to make clear that should Iran, its partners or its proxies, use this moment to target American personnel or interests in the region, the United States will take every measure necessary to defend our people.

    Shifting gears, tomorrow is Election Day and DOD stands prepared to support state and local authorities as required. Of note, Secretary Austin approved a request last week from the District of Columbia for D.C. National Guard troops to support the D.C. Fire and Emergency Medical Services from November 5 through 13. For those of you who have covered the defense beat for a while, you know that it is routine practice for the DOD to authorize the D.C. National Guard to support or augment security for large scale events in the district and activated Guardsmen will remain under the command and control of the D.C. National Guard.

    Similarly, around the nation, approximately 60 National Guardsmen from six states have been activated by their state governors and state active-duty status for election support with roughly another 600 Guardsmen from 17 states on standby if needed. Again, as you know, the National Guard has ongoing and long-standing relationships with local, state and federal agency partners and has assisted with national special security events like Election Day and Inauguration Day for many years. For more information about individual state responses and activations, I would direct you to the individual states.

    And finally, the Department is proud to celebrate National Native American Heritage Month. This November, we honor the contributions and sacrifices of native peoples who have served our country. The contributions of these fellow Americans have been pivotal in some of the most critical moments in our nation’s defense.

    As just one of many examples, the US Marine Corps Navajo code talkers using their native language to develop an unbreakable communication code during World War II, played a decisive role in the Battle of Iwo Jima. Their example of duty and honor continues to inspire current and future generations of Americans to serve with the same resolve and pride.

    And with that, I’ll be glad to take your questions. Start with AP, Lita.

    Q:  Thank you, Pat. Two things, one on Ukraine, North Korea. Can you say whether any North Korean troops have been observed in combat or over the line in Ukraine? And I believe State has said that the number is about 10,000. Is that what you believe are in the Kursk region right now? And then I have a—

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Sure, a couple updates. So we believe that there are now at least 10,000 DPRK forces in the Kursk Oblast. Recognizing that as we continue to assess DPRK presence on the ground, those numbers could go up slightly, in terms of the total number of DPRK troops in Russia. We’ve seen the press reports about alleged combat ops. We’re looking into those, but at this point cannot corroborate those reports. But as you heard Secretary Austin say last week, should these troops engage in combat support operations against Ukraine, they would become legitimate military targets.

    Q:  So have you seen any additional North Korean forces heading for eastern Russia? Do you see another wave of influx?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  I don’t know that I would call it a wave, but as we look at those numbers, we think that the total number of DPRK forces in Russia total could be closer to around 11,000 to 12,000, with about 10,000, at least 10,000 right now in the Kursk Oblast. OK. And you said you had a follow-up?

    Q:  Just on Iran, have you seen any movement indications or any suggestions that Iran has been taking steps to do any type of retaliatory action against Israel?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah. So in terms of whether or not Iran does anything, I’m not going to speculate, nor will I discuss intelligence assessments from here. I think we as the US government have been very clear that we believe Iran should not respond to Israel’s retaliation if they choose to do so. We of course will support Israel and their defense.

    Natasha?

    Q:  Thanks, Pat. So senior Ukrainian officials have said that they are observing some very small, limited numbers of North Korean troops, things like engineers, for example, in the occupied territories in eastern Ukraine. Are you not prepared to corroborate that at this point?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah. Again, we’re looking into all of that, but at this point, just can’t corroborate those reports.

    Q:  OK. And also, we’re about a week away from the deadline that was set by Secretary Austin and Secretary Blinken with regard to Gaza. The State Department just said that they have not yet seen enough being done in northern Gaza in terms of humanitarian aid. Does the Secretary agree with that?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Well, I think as you highlight, at the State Department on Thursday, when Secretary Blinken and Secretary Austin addressed this, both of them highlighted that we believe more needs to be done in terms of getting humanitarian assistance into Gaza and to the Palestinian people. I’d point you to Secretary Blinken’s remarks in terms of sort of the rundown of where things stand on that front.

    But even in his call last week on Thursday with Minister Gallant, Secretary Austin continues to reinforce how important it is to ensure that humanitarian assistance can flow and flow faster into Gaza. And so that will continue to be something that we will remain focused on. Constantin?

    Q:  Thanks, Pat. Just one follow up on the National Guard deployments. You said Guardsmen have been put on active orders from six states. Can you say what those six states are?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  I don’t have that list here in front of me. Let me just double check, Constantin, make sure. I don’t have that list here in front of me, but we can certainly get that for you.

    Q:  OK. And then sort of on the same vein, is the Department of Defense providing any cyber resources or capabilities for election monitoring or sort of anti-misinformation efforts?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Well, as you know, US Cyber Command does play a role in terms of supporting our elections. I’d refer you to them to go into details and there are National Guard elements that do support US Cyber Command, but they can provide you more details on that.

    Q:  Thank you.

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Thank you. Noah?

    Q:  A couple clean up questions on North Korea, the 11,000 to 12,000 number that you said, that leaves a bandwidth between those in Kursk and those still in eastern Russia. Do you expect those remaining troops to head toward Kursk in the coming days?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah. I mean, again we fully expect, just based on what we’re seeing, that these forces will go to the Kursk region, that they will provide some kind of capability. All indications are that they will provide some type of combat or combat support capability. Again, remains to be seen exactly how they will be employed. I’d point you to the comments that were made on Thursday in terms of things like UAV ops, artillery, infantry. So again, should they be employed in combat, they will become legitimate military targets and we would fully expect that the Ukrainians would do what they need to do to defend themselves and their personnel.

    Q:  And do all of those in Kursk that are North Korean troops have Russian uniforms and equipment at this point as you understand?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  My understanding is that all of these forces are being issued Russian uniforms and Russian equipment.

    Q:  One more follow up on the Middle East. The deployments that were announced on Friday, are these based on new assessments of the threat that Iran may pose within a retaliation toward Israel or possibly American troops? Or is this simply about trying to reinforce the US force posture there given that the carrier will depart in the coming weeks?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Well, I think as we highlighted in our statement and as I highlighted at the top here, we are deploying these forces to the region to preserve our ability to protect our forces, support the defense of Israel and also act as a deterrent capability. And so out of due diligence in ensuring that we continue to be prepared to meet our commitments, deploying and rotating these forces in as we look ahead down the road and prepare for the departure of the Abe (sic).

    OK. Mike.

    Q:  Yeah, these North Korean units, do you know if the soldiers are filling blanks spots in the Russian line or will they be deploying and operating as their own particular units?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  So a couple of things. It’s TBD (sic). We’ll see exactly how these forces are integrated into Russian operations and how they’re committed to the battlefield, assuming that they are. In terms of replacement for Russian forces, I’d point you back again to what Secretary Austin highlighted in terms of the significant casualty rates that we’re seeing among Russian forces.

    So insomuch as that these are potentially forces that are coming in to replace the massive numbers of losses that Russia is experiencing, I think that’s probably a fair assessment and I certainly would not want to be a North Korean soldier.

    Q:  Right. But my point is, I mean, are they going to be inserted into already existing Russian units as just spare body, spare body, spare body, or will there be North Korean battalion fighting here and North Korean battalion here, or do you not know at this point?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah, we don’t know at this point, and we’ll see. We anticipate in the relatively near future we will know more as we see how Russia and North Korea opt to employ these forces. OK. Charlie?

    Q:  Thank you, General. Adding to that, do you anticipate or are you even tracking whether or not this may just be the first of many North Koreans that will be headed to Russia? That’s my first question. My second question is regarding Iran’s threats of retaliation, they said that it will come from Iran or Iranian-backed militias, which we’ve already seen in Iraq.

    First of all, have you seen an uptick in the tempo of drone attacks from Iranian-backed militias there against Israel and or against US forces? Does it look orchestrated and how much of it is a concern that bigger stuff might be headed there like ballistic missiles?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah, on your first question, that is definitely something that we’re keeping a close eye on. I don’t have anything right now to pass along in terms of whether or not DPRK will or won’t send additional forces. And I’m not going to speculate on whether they do, but definitely something we’re keeping a close eye on. As far as the threats that have been communicated in the press and in social media about the potential for Iran to launch attacks from Iraqi territory, what I would say is that over the last year, we’ve seen Iran backed militia groups sporadically launch missiles and one-way attack UAVs from Syria and Iraq towards Israel.

    The vast majority of those have been intercepted or fail in flight. And while we’ve recently observed an increase in one way attack UAVs assessed to be against Israel, at this stage, we would not characterize these as large numbers. And so we continue to remain vigilant, and we remain ready to defend US forces and Israel from these threats.

    Q:  And are you tracking any movement of ballistic missiles in and out of that region?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  I don’t have anything to pass along in terms of intelligence assessments from this podium, but again, we stand ready to support the defense of Israel and would encourage Iran not to launch any type of retaliatory attack.

    Luis?

    Q:  We’ve been talking about the 10,000 troops in Kursk, but can you give us some context please? This 10,000, how much will they augment the Russian presence there? Will they be a significant portion of the presence there in that particular oblast? Are they a very small component? Just something so that we can understand what adding 10,000 North Koreans to that battle space means.

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Sure. I think to do that, you have to go back in time a little bit. And if you recall, when Ukraine conducted their offensive into Russian territory into the Kursk Oblast and they continue to hold Russian territory in Kursk and they have made the decision to hold that territory at risk and continue to defend it. And so what we saw in the early days of that Ukrainian offensive was a very muddled Russian response in terms of trying to push the Ukrainians back. And for the most part, they have not been able to push the Ukrainians very far. They’ve taken some incremental amounts of territory back but nothing that we would categorize as significant. So placing these additional 10,000 to 11,000 to 12,000 forces in Kursk is definitely something from a combat capability standpoint that could be significant, but a lot of that will depend on how those forces are employed, how they’re integrated into the Russian command and control.

    And of course, if the Ukrainians—if the past is any indicator of the future, the Ukrainians are battle hardened veterans who know how to fight. And so every indication that they will continue to defend Ukrainian sovereignty and continued to defend Kursk, the territory that they’ve taken. And so we’ll see how that plays out.

    Q:  Numerically and size-wise, numerically, is it, the infusion of these 10,000 additional troops at a minimum, is that really significant to the force that you said have been making incremental gains?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Well, I think, again, if you want to talk numbers and again, numbers can be misleading because look what Ukraine did when Russia invaded Ukraine in 2022 and how a small number of forces to date have been able to largely defeat the strategic objectives of what was and is the largest army in Europe.

    So again, a lot of that just depends on how Russia opts to employ those forces, how well they’re integrated, what kind of combat experience they have. And so we’ll see. In the meantime, we continue to consult very closely with our allies and partners. And we also continue to ensure that we’re working with Ukraine and some 50 nations to rush security assistance to Ukraine, to defend Ukrainian sovereignty both here and elsewhere in the battlefield.

    Let me go to the phone real quick here. Let’s go to Dan Lamothe, Washington Post.

    Q:  Hey, General. Thanks for your time today. There’s often a perception in the Pentagon and across Washington that aircraft carriers deter Iran and the lack of one in the region, emboldens them. Two questions, I guess, related. Does Secretary Austin see these newly announced deployments on Friday to the region as sufficient to deter Iran with a carrier group potentially coming?

    And can you put this decision in context of how you’re looking at broader threats in the Pacific and other regions? Thanks.

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah. Thanks, Dan. So when it comes to us force deployments around the world, while there’s understandable focus on particular types of equipment and vessels to include aircraft carriers, at the end of the day, it really comes down to our people and the capabilities that we provide. And so the capabilities that we’re deploying into the region will provide a significant amount of capability on par with what we’ve been doing in the Middle East region since the October 7th attacks over a year ago.

    And so certainly as we look at global force management and our national security commitments around the world, that’s always taking into account in terms of how we can meet those commitments and ensure we have what we need to protect our people. And in this case, also support the defense of Israel.

    Let me go to Jeff Schogol, Task and Purpose.

    Q:  Yeah. Thank you. Two separate questions. Now that the election is upon us, is the Defense Department satisfied that all overseas troops and their spouses have the access they need to federal absentee ballots? Also, how should one describe the coalition between North Korea and Russia? Is it an alliance or is it more friends with benefits?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Thanks, Jeff. Let me take your question on voting first. So first of all, we continue to recommend all voters register and request an absentee ballot. Those deadlines vary depending on states. And as you know, we do have a robust education program in terms of getting the word out on how service members and their families can obtain their absentee ballots no matter where you are, whether it’s overseas or whether it’s stationed outside of your state.

    Just speaking from personal experience as a Florida resident, I can tell you, I received multiple emails over many weeks, reminding me to register and to request my ballot. It arrived early. I had plenty of time to submit that. If a service member has requested a ballot and it hasn’t arrived, they can use the federal write-in absentee ballot immediately at FVAP.gov/FWAB, and this acts as a back-up ballot.

    And again, that information is provided on multiple occasions through multiple mechanisms. So again, encourage folks to get out and vote and make sure that their voice is heard. As far as the relationship between Russia and North Korea goes, we definitely continue to monitor this.

    The level of cooperation between the two remains concerning, but in many ways transactional. And so again, this is something we’ll keep a close eye on, and I’ll just leave it there. OK. Yes, sir.

    Q:  Thank you, General. Last week as you said that Secretary Austin all times (sic) he urged for a ceasefire in Lebanon as quickly as possible. So do you think we need more time, that Israel needs more time to stop this war to achieve their goals? How long do you believe that will take, this war? Is it, as you said before, it was a limited operations, but now almost a month starting this war, so do they need more weeks and months or maybe we’re going to see like what’s happened in Gaza like over a year for this war? Thank you.

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah, I won’t speak for Israel. But Secretary Austin and others have been very clear that we believe that a ceasefire and the resolution of tensions in the region through diplomatic means are required as soon as possible. And so as you’ve seen with the State Department and the US envoy, Mr. Hochstein, going to the region, this continues to be something that is a top priority for the US, working with partners in the region to include Israel. And we’ll continue to communicate that to our Israeli counterparts.

    As you saw from our readout, this was also something that came up in the phone call between Secretary Austin and Minister Gallant last week. Thank you.

    OK. Let me go to Heather from USNI.

    Q:  Thank you so much. I was hoping you could give a couple more details about the plans with Abe (sic) and then whether or not it’s planning to leave within the next couple of weeks, the next week. And then Harry S. Truman is on its way over to the Middle East, Mediterranean area, but it’s making stops along its way.

    Is this an indication that we don’t feel that there needs to be an aircraft carrier in the region very quickly? What does this indicate in terms of how much the Houthi threat remains in the Middle East?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Yeah. Thanks, Heather. As far as deployment timelines go, as a matter of policy and operational security, we’re not going to talk specifics on when the Abraham Lincoln strike group will depart the US Central Command area of responsibility. As for the Truman, as you highlight, continues to operate in the North Atlantic.

    Again, I’m not going to get into its particular movements or forecast those. And in terms of the message it sends, it just demonstrates the flexibility and versatility of the US military and our ability to meet our national security commitments and provide robust capability around the world and flex as needed.

    And again highlighted by the fact that you have B-52 bombers that are now in the AOR, the CENTCOM AOR, that are multi-versatile and can provide an incredible amount of capability in support of those efforts. So again, it’s about capability and it’s about our people and we’re confident that we have the right force posture to support our national security requirements.

    Ashley?

    Q:  Just a quick follow up on the announcement on troops at the Middle East, are there any plans to send additional troops into Israel or to man assets there?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  I don’t have anything to announce at this point. Yeah. Thanks.

    Sir?

    Q:  Thank you. General. Do you anticipate any direct Israeli attack on Iranian paramilitary groups in Iraq as they continuously launch UAVs into Israel? I mean, did you send any message to these groups in Iraq?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  As I’m sure you can appreciate, I won’t speak for Israeli operations on what they may or may not do. I can tell you that what we’ve seen in the past is them—as I highlighted earlier, intercept threats that are heading towards Israel, but in terms of potential future military action by Israel, that’s a question for them to address. OK.

    Q:  Might that not be something that CENTCOM would engage in, the potential attack or if you want to call it a preemptive strike?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Well, again, without getting into hypotheticals or speaking to Israeli operations, US Central Command and the Department of Defense regularly have conversations with Israel as it relates to the defense of Israel and how we can work together to support that effort. And as I highlighted earlier, if we do see threats emanating from other regions, we’re prepared to support the defense of Israel and have, as we’ve demonstrated in the past.

    Howard Altman, War Zone.

    Q:  Hey. Thanks, Pat. A couple things I wanted to drill down a little bit on the North Koreans in Kursk. Images appeared online that shows a North Korean troop killed in that, in Kursk. And then my other question is, has there been any change in the US warship presence in the Red Sea to protect shipping commercial shipping?

    And if so, how has that changed? Any change in operation—I forget what the name is, the operation protecting ships in the Red Sea?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Thanks, Howard. On your first question, again, I’ve seen those press and social media reports. Again, we’re looking into them, but I cannot corroborate those reports at this time. As it relates to force posture in the Red Sea and elsewhere, I’m not going to get into specifics in terms of which ships are there and what their movement plans are, other than to say, yes, we do maintain robust capability to support Operation Prosperity Guardian and support our efforts to support freedom of navigation and the safety of mariners in the region. OK.

    Do one more. Yes, ma’am?

    Q:  Just a quick follow-up, Pat, on Luis’ questions. What’s the US estimate on the number of Russian forces in the Kursk region?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  I don’t have a number to provide to you.

    Q:  Ballpark?

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  I don’t even have a ballpark number other than to say, broadly speaking, what we saw in the past was essentially a conglomeration of various units on the Russian side to include territorial defense forces attempting to push the Ukrainians back.

    Q:  I think I was just trying to get a sense of kind of perspective, right? Is it now almost largely North Korean troops their equal number of both? I mean, I think that’s kind of what we’re trying to figure out.

    PENTAGON PRESS SECRETARY MAJOR GENERAL PAT RYDER:  Sure. And I just don’t have a number to pass along here. I mean, keeping in mind again that what we’re talking about here is Russian territory writ large, right? So I mean this is inside Russian interior lines and theoretically, Russia could have made the decision a long time ago to move large number of Russian forces to address this threat.

    But it demonstrates a couple of things. One, the fact that Russia has not made recovery of its sovereign territory a priority, and number two, the fact that Russia finds itself in a situation where they now have to hire out to get additional forces to deal with this issue, which as Secretary Austin has highlighted, is an indication of the dire straits they’re in when it comes to personnel.

    So thank you very much, everybody. Appreciate it.

    MIL OSI USA News

  • MIL-OSI Canada: Prime Minister Justin Trudeau meets with United Nations High Commissioner for Refugees Filippo Grandi

    Source: Government of Canada – Prime Minister

    Today, Prime Minister Justin Trudeau met with the United Nations High Commissioner for Refugees, Filippo Grandi.

    Prime Minister Trudeau and High Commissioner Grandi discussed the unprecedented nature of the current global refugee crisis, which is fuelled by more intense and longer lasting conflicts and the growing effects of climate change. The Prime Minister recognized the valuable role that the High Commissioner and his office (UNHCR) play in providing protection and humanitarian assistance to refugees and other forcibly displaced people.

    Prime Minister Trudeau expressed his concern over the growing humanitarian impacts arising from the situation in the Middle East and acknowledged the important role that the UNHCR is playing in responding to the needs of those forcibly displaced in both Lebanon and Syria. The two leaders also discussed the human dimension of Russia’s war of aggression against Ukraine, including its impacts on internally displaced people and refugees. Additionally, Prime Minister Trudeau expressed his concern over the humanitarian impacts of the crisis in Sudan and underscored Canada’s support for those affected by it.

    The Prime Minister strongly underscored Canada’s commitment to the UNHCR and its support for the organization’s work to make a positive difference in the lives of refugees. Prime Minister Trudeau thanked the High Commissioner for the UNHCR’s dedication to protecting the most vulnerable in difficult circumstances.

    The two leaders reaffirmed the strong partnership between Canada and the UNHCR, and they agreed to stay in close contact.

    Associated Links 

    MIL OSI Canada News

  • MIL-OSI: International Petroleum Corporation Announces Third Quarter 2024 Financial and Operational Results

    Source: GlobeNewswire (MIL-OSI)

    TORONTO, Nov. 05, 2024 (GLOBE NEWSWIRE) — International Petroleum Corporation (IPC or the Corporation) (TSX, Nasdaq Stockholm: IPCO) today released its financial and operational results and related management’s discussion and analysis (MD&A) for the three and nine months ended September 30, 2024.

    William Lundin, IPC’s President and Chief Executive Officer, comments: “We are pleased to announce another positive quarter of operational performance. IPC achieved average net daily production during the third quarter of 45,000 barrels of oil equivalent per day (boepd), following planned maintenance shutdowns during the quarter. We also continue to purchase IPC common shares under the normal course issuer bid (NCIB). We have now almost completed the 2023/2024 NCIB, reducing the outstanding number of common shares by over 6% since the beginning of December 2023. We intend to seek Toronto Stock Exchange approval to renew the NCIB in December 2024. We are also pleased to report on the progress achieved at the Blackrod Phase 1 development in Canada, which remains on schedule and on budget.”

    Q3 2024 Business Highlights

    • Average net production of approximately 45,000 boepd for Q3 2024, in line with guidance (49% heavy crude oil, 17% light and medium crude oil and 34% natural gas).(1)
    • Successful completion of planned maintenance shutdowns at Onion Lake Thermal (OLT) in Canada and the Bertam field in Malaysia.
    • Drilling activity at the Suffield area in Canada continued with four wells drilled in Q3 2024 and completed by October 2024.
    • Development activities on Phase 1 of the Blackrod project continue to progress on schedule and on budget, with forecast first oil in late 2026.
    • 2.6 million IPC common shares purchased and cancelled during Q3 2024 under IPC’s normal course issuer bid (NCIB), on track to complete the 2023/2024 NCIB during November 2024.
    • IPC plans to seek Toronto Stock Exchange approval for the renewal of the NCIB in December 2024.

    Q3 2024 Financial Highlights

    • Operating costs per boe of USD 17.9 for Q3 2024, below guidance.(3)
    • Operating cash flow (OCF) and Earnings Before Interest, Tax, Depreciation and Amortization (EBITDA) of MUSD 73 and MUSD 68 respectively in line with guidance for Q3 2024.(3)
    • Capital and decommissioning expenditures of MUSD 102 for Q3 2024, in line with guidance.
    • Free cash flow (FCF) for Q3 2024 amounted to MUSD -38 (MUSD 44 pre-Blackrod Phase 1 project funding).(3)
    • Gross cash of MUSD 299 and net debt of MUSD 157 as at September 30, 2024.(3)
    • Net result of MUSD 23 for Q3 2024.

    Reserves and Resources

    • Total 2P reserves as at December 31, 2023 of 468 MMboe, with a reserves life index (RLI) of 27 years.(1)(2)
    • Contingent resources (best estimate, unrisked) as at December 31, 2023 of 1,145 MMboe.(1)(2)

    2024 Annual Guidance

    • Full year 2024 average net production guidance range maintained at 46,000 to 48,000 boepd.(1)
    • Full year 2024 operating costs guidance revised to below USD 18 per boe.(3)
    • Full year 2024 OCF guidance estimated at between MUSD 335 and 342, assuming Brent USD 70 to 80 per barrel for the remainder of 2024.(3)
    • Full year 2024 capital and decommissioning expenditures guidance forecast maintained at MUSD 437.
    • Full year 2024 FCF guidance estimated at between MUSD -140 and -133 (between MUSD 222 and 229 pre-Blackrod Phase 1 project funding), assuming Brent USD 70 to 80 per barrel for the remainder of 2024.(3)
      Three months ended
    September 30
      Nine months ended
    September 30
    USD Thousands 2024   2023     2024   2023  
    Revenue 173,200   257,366     598,659   655,446  
    Gross profit 39,505   93,429     167,397   210,559  
    Net result 22,875   71,681     101,804   143,269  
    Operating cash flow (3) 72,589   119,142     263,831   279,414  
    Free cash flow (3) (38,269 ) 34,703     (74,021 ) 67,379  
    EBITDA (3) 68,313   123,054     259,304   284,334  
    Net cash/(debt) (3) (157,228 ) 83,097     (157,228 ) 83,097  
                       

    Oil prices softened in the third quarter with Brent prices averaging USD 80 per barrel compared with USD 85 per barrel in the second quarter. Volatility during the quarter was high with Brent prices ranging from USD 89 per barrel in July to USD 70 per barrel in September. Notwithstanding the volatility in prices, the crude market was in a deficit through the third quarter, aided by the proactive supply management by the OPEC+ group. The continued conflicts in the Middle East and Ukraine led to increased oil prices, though these were partially offset by concerns over global oil demand growth, in particular consumer and industrial demand in China. Despite some of these negative factors, the physical market remains tight with OECD crude stock levels below the five-year average, with oil demand expected to be at an all-time high in 2024 and continue to grow in 2025. Approximately 50% of IPC’s forecast 2024 oil production is hedged at USD 80 per barrel WTI or USD 85 per barrel Dated Brent through to the end of 2024.

    The third quarter 2024 WTI to Western Canadian Select (WCS) price differentials averaged just under USD 14 per barrel, in line with the second quarter and approximately USD 5 per barrel lower than the first quarter differential average of USD 19 per barrel. The Trans Mountain expansion (TMX) pipeline continues to support tighter differentials with the Western Canadian Sedimentary Basin (WCSB) now having excess spare pipeline capacity for the first time in more than a decade. Crude exports from the new TMX pipeline are flowing off the coast of British Columbia, with deliveries to the US West Coast and Asia creating new end destinations for Canadian heavy oil. Around 70% of our forecast 2024 Canadian WCS production volumes are hedged at a WTI/WCS differential of USD 15 per barrel.

    Natural gas prices in Canada remained suppressed in the third quarter, with AECO pricing averaging CAD 0.67 per Mcf during the period, compared to CAD 1.17 per Mcf average for the second quarter. This has led to some Canadian natural gas producers curtailing production as western Canada gas storage levels continue to sit above the five-year range. IPC implemented hedges during the third quarter for approximately 14,500 Mcf per day at CAD 1.57 per Mcf from August to year end 2024.

    Third Quarter 2024 Highlights and Full Year 2024 Guidance

    IPC delivered average daily production rates of 45,000 boepd for the third quarter. The average daily production for the first nine months of 2024 was 47,400 boepd and the full year Capital Markets Day (CMD) production guidance of 46,000 to 48,000 boepd is maintained. During the third quarter, planned maintenance shutdowns at the Onion Lake Thermal (OLT) asset in Canada and at the Bertam field in Malaysia were successfully completed. High uptimes were achieved across all major producing assets in our portfolio during the quarter and the business benefited from the oil wells drilled within our Southern Alberta assets and the new wells brought on stream from sustaining Pad L at the OLT asset.(1)

    Operating costs in the third quarter of 2024 were below forecast at USD 17.9 per boe. The lower costs were largely driven by lower energy input costs within our Canadian asset base. Full year 2024 operating costs guidance is revised to less than USD 18 per boe, below the CMD guidance range of USD 18 to 19 per boe.(3)

    Operating cash flow (OCF) for the third quarter of 2024 was USD 73 million in line with forecast. Full year 2024 OCF guidance is revised to USD 335 to 342 million (assuming Brent USD 70 to 80 per barrel for the remainder of 2024).(3)

    Capital and decommissioning expenditure for the third quarter was in line with plan at USD 102 million. Our full year 2024 capital and decommissioning expenditure guidance is unchanged at USD 437 million.

    Free cash flow (FCF) was USD -38 million (or USD 44 million pre-Blackrod Phase 1 development funding) during the third quarter of 2024. Full year 2024 FCF guidance is revised to USD -140 to -133 million (or USD 222 to 229 million pre-Blackrod Phase 1 development funding) assuming Brent USD 70 to 80 per barrel for the remainder of 2024.(3)

    Net debt was increased during the third quarter of 2024 by approximately USD 69 million to USD 157 million.(3) This is due to the growth capital expenditure at the Blackrod Phase 1 project and continued funding of the normal course issuer bid (NCIB) share repurchase program. The gross cash position as at September 30, 2024 was USD 299 million. In the third quarter, IPC enhanced its financing position by entering into a letter of credit facility in Canada to cover all of its existing operational letters of credit, giving full availability under IPC’s undrawn CAD 180 million Revolving Credit Facility.

    With a robust balance sheet and strong cashflow generation from the producing assets, IPC is strongly positioned to deliver on our three strategic pillars of organic growth, shareholder returns and pursue value-adding M&A.

    Blackrod Phase 1 Project

    The Blackrod asset is 100% owned by IPC and hosts the largest booked reserves and contingent resources within the IPC portfolio. After more than a decade of pilot operations, subsurface delineation and commercial engineering studies, IPC sanctioned the Phase 1 development in the first quarter of 2023. The Phase 1 development targets 218 MMboe of 2P reserves, with a multi-year forecast capital expenditure of USD 850 million to first oil planned in late 2026. The Phase 1 development is planned for plateau production of 30,000 bopd which is expected by early 2028.(1)(2)

    2024 marks a peak investment year at the Blackrod Phase 1 project for IPC, with USD 362 million planned to be spent in the year. Project progress has advanced according to plan, with approximately USD 245 million spent through the first nine months of 2024. All major third-party contracts have been executed, including but not limited to, the engineering, procurement and construction (EPC) agreements for the central processing facility (CPF) and well pad facilities, midstream agreements for the input fuel gas, diluent and oil blend pipelines, and drilling rig and stakeholder agreements. All major long lead items have been procured and pre-operations onboarding continues as the asset undergoes rapid change from a pilot steam assisted gravity drainage (SAGD) operation to a commercial SAGD operation. IPC’s core operational philosophy is to responsibly develop and commission projects with the staff that are going to manage and operate the asset to ensure the seamless transition from development to operations.

    As at the end of the third quarter of 2024, over half of the Blackrod Phase 1 development capital had been spent since the project sanction in early 2023. All major work streams are progressing as planned and the focus continues to be on executing the detailed sequencing of events as facility modules are safely delivered and installed at site. The total Phase 1 project guidance of USD 850 million capital expenditure to first oil in late 2026 is unchanged. IPC intends to fund the remaining Blackrod Phase 1 development costs with forecast cash flow generated by its operations and cash on hand.

    Stakeholder Returns: Normal Course Issuer Bid

    Under the current 2023/2024 NCIB, IPC has the ability to repurchase up to approximately 8.3 million common shares over the period of December 5, 2023 to December 4, 2024. IPC repurchased and cancelled approximately 7.5 million common shares up to the end of September 2024. The average price of common shares purchased under the 2023/2024 NCIB was SEK 132 / CAD 17 per share. IPC expects to complete the 2023/2024 NCIB during November 2024, resulting in the cancellation of 6.5% of the total number of common shares outstanding as at the beginning of December 2023.

    As at September 30, 2024, IPC had a total of 120,751,038 common shares issued and outstanding and IPC held 30,000 common shares in treasury. As at October 31, 2024, IPC had a total of 120,244,638 common shares issued and outstanding and IPC held 44,400 common shares in treasury.

    The IPC Board of Directors has approved, subject to acceptance by the Toronto Stock Exchange (TSX), the renewal of IPC’s NCIB for a further twelve months from December 2024 to December 2025. We expect that the 2024/2025 NCIB will permit IPC to purchase on the TSX and/or Nasdaq Stockholm, and cancel, up to a further approximately 7.5 million common shares, representing approximately 6.2% of the total outstanding common shares (or 10% of IPC’s “public float” under applicable TSX rules) following completion of the current 2023/2024 NCIB. IPC continues to believe that reducing the number of common shares outstanding while in parallel investing in material production growth at the Blackrod project will prove to be a winning formula for our stakeholders.

    Environmental, Social and Governance (ESG) Performance

    As part of IPC’s commitment to operational excellence and responsible development, its objective is to reduce risk and eliminate hazards to prevent occurrence of accidents, ill health, and environmental damage, as these are essential to the success of our business operations. During the third quarter of 2024, IPC recorded no material safety or environmental incidents.

    As previously announced, IPC targets a reduction of our net GHG emissions intensity by the end of 2025 to 50% of IPC’s 2019 baseline and IPC remains on track to achieve this reduction. During the first quarter of 2024, IPC announced the commitment to remain at end 2025 levels of 20 kg CO2/boe through to the end of 2028.(4)

    Notes:

    (1) See “Supplemental Information regarding Product Types” in “Reserves and Resources Advisory” below. See also the annual information form for the year ended December 31, 2023 (AIF) available on IPC’s website at www.international-petroleum.com and under IPC’s profile on SEDAR+ at www.sedarplus.ca.
    (2) See “Reserves and Resources Advisory“ below. Further information with respect to IPC’s reserves, contingent resources and estimates of future net revenue, including assumptions relating to the calculation of NPV, are described in the AIF.
    (3) Non-IFRS measures, see “Non-IFRS Measures” below and in the MD&A.
    (4) Emissions intensity is the ratio between oil and gas production and the associated carbon emissions, and net emissions intensity reflects gross emissions less operational emission reductions and carbon offsets.

    International Petroleum Corp. (IPC) is an international oil and gas exploration and production company with a high quality portfolio of assets located in Canada, Malaysia and France, providing a solid foundation for organic and inorganic growth. IPC is a member of the Lundin Group of Companies. IPC is incorporated in Canada and IPC’s shares are listed on the Toronto Stock Exchange (TSX) and the Nasdaq Stockholm exchange under the symbol “IPCO”.

    For further information, please contact:

    Rebecca Gordon
    SVP Corporate Planning and Investor Relations
    rebecca.gordon@international-petroleum.com
    Tel: +41 22 595 10 50
          Or       Robert Eriksson
    Media Manager
    reriksson@rive6.ch
    Tel: +46 701 11 26 15
             

    This information is information that International Petroleum Corporation is required to make public pursuant to the EU Market Abuse Regulation and the Securities Markets Act. The information was submitted for publication, through the contact persons set out above, at 07:30 CET on November 5, 2024. The Corporation’s unaudited interim condensed consolidated financial statements (Financial Statements) and management’s discussion and analysis (MD&A) for the three and nine months ended September 30, 2024 have been filed on SEDAR+ (www.sedarplus.ca) and are also available on the Corporation’s website (www.international-petroleum.com).

    Forward-Looking Statements
    This press release contains statements and information which constitute “forward-looking statements” or “forward-looking information” (within the meaning of applicable securities legislation). Such statements and information (together, “forward-looking statements”) relate to future events, including the Corporation’s future performance, business prospects or opportunities. Actual results may differ materially from those expressed or implied by forward-looking statements. The forward-looking statements contained in this press release are expressly qualified by this cautionary statement. Forward-looking statements speak only as of the date of this press release, unless otherwise indicated. IPC does not intend, and does not assume any obligation, to update these forward-looking statements, except as required by applicable laws.

    All statements other than statements of historical fact may be forward-looking statements. Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, forecasts, guidance, budgets, objectives, assumptions or future events or performance (often, but not always, using words or phrases such as “seek”, “anticipate”, “plan”, “continue”, “estimate”, “expect”, “may”, “will”, “project”, “forecast”, “predict”, “potential”, “targeting”, “intend”, “could”, “might”, “should”, “believe”, “budget” and similar expressions) are not statements of historical fact and may be “forward-looking statements”.

    Forward-looking statements include, but are not limited to, statements with respect to:

    • 2024 production ranges (including total daily average production), production composition, cash flows, operating costs and capital and decommissioning expenditure estimates;
    • Estimates of future production, cash flows, operating costs and capital expenditures that are based on IPC’s current business plans and assumptions regarding the business environment, which are subject to change;
    • IPC’s financial and operational flexibility to continue to react to recent events and navigate the Corporation through periods of volatile commodity prices;
    • The ability to fully fund future expenditures from cash flows and current borrowing capacity;
    • IPC’s intention and ability to continue to implement strategies to build long-term shareholder value;
    • The ability of IPC’s portfolio of assets to provide a solid foundation for organic and inorganic growth;
    • The continued facility uptime and reservoir performance in IPC’s areas of operation;
    • Development of the Blackrod project in Canada, including estimates of resource volumes, future production, timing, regulatory approvals, third party commercial arrangements, breakeven prices and net present value;
    • Current and future production performance, operations and development potential of the Onion Lake Thermal, Suffield, Brooks, Ferguson and Mooney operations, including the timing and success of future oil and gas drilling and optimization programs;
    • The potential improvement in the Canadian oil egress situation and IPC’s ability to benefit from any such improvements;
    • The ability to maintain current and forecast production in France and Malaysia;
    • The intention and ability of IPC to acquire further common shares under the NCIB, including the timing of any such purchases;
    • The ability of IPC to renew the NCIB and the number of common shares which may be purchased under a renewed NCIB;
    • The return of value to IPC’s shareholders as a result of the NCIB;
    • The ability of IPC to implement further shareholder distributions in addition to the NCIB;
    • IPC’s ability to implement its greenhouse gas (GHG) emissions intensity and climate strategies and to achieve its net GHG emissions intensity reduction targets;
    • IPC’s ability to implement projects to reduce net emissions intensity, including potential carbon capture and storage;
    • Estimates of reserves and contingent resources;
    • The ability to generate free cash flows and use that cash to repay debt;
    • IPC’s continued access to its existing credit facilities, including current financial headroom, on terms acceptable to the Corporation;
    • IPC’s ability to maintain operations, production and business in light of any future pandemics and the restrictions and disruptions related thereto, including risks related to production delays and interruptions, changes in laws and regulations and reliance on third-party operators and infrastructure;
    • IPC’s ability to identify and complete future acquisitions;
    • Expectations regarding the oil and gas industry in Canada, Malaysia and France, including assumptions regarding future royalty rates, regulatory approvals, legislative changes, and ongoing projects and their expected completion; and
    • Future drilling and other exploration and development activities.

    Statements relating to “reserves” and “contingent resources” are also deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and that the reserves and resources can be profitably produced in the future. Ultimate recovery of reserves or resources is based on forecasts of future results, estimates of amounts not yet determinable and assumptions of management.

    Although IPC believes that the expectations and assumptions on which such forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because IPC can give no assurances that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks.

    These include, but are not limited to general global economic, market and business conditions; the risks associated with the oil and gas industry in general such as operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of estimates and projections relating to reserves, resources, production, revenues, costs and expenses; health, safety and environmental risks; commodity price fluctuations; interest rate and exchange rate fluctuations; marketing and transportation; loss of markets; environmental and climate-related risks; competition; innovation and cybersecurity risks related to our systems, including our costs of addressing or mitigating such risks; the ability to attract, engage and retain skilled employees; incorrect assessment of the value of acquisitions; failure to complete or realize the anticipated benefits of acquisitions or dispositions; the ability to access sufficient capital from internal and external sources; failure to obtain required regulatory and other approvals; geopolitical conflicts, including the war between Ukraine and Russia and the conflict in the Middle East, and their potential impact on, among other things, global market conditions; and changes in legislation, including but not limited to tax laws, royalties, environmental and abandonment regulations.

    Additional information on these and other factors that could affect IPC, or its operations or financial results, are included in the MD&A (See “Risk Factors”, “Cautionary Statement Regarding Forward-Looking Information” and “Reserves and Resources Advisory” therein), the Corporation’s Annual Information Form (AIF) for the year ended December 31, 2023, (See “Cautionary Statement Regarding Forward-Looking Information”, “Reserves and Resources Advisory” and “Risk Factors”) and other reports on file with applicable securities regulatory authorities, including previous financial reports, management’s discussion and analysis and material change reports, which may be accessed through the SEDAR+ website (www.sedarplus.ca) or IPC’s website (www.international-petroleum.com).

    Management of IPC approved the production, operating costs, operating cash flow, capital and decommissioning expenditures and free cash flow guidance and estimates contained herein as of the date of this press release. The purpose of these guidance and estimates is to assist readers in understanding IPC’s expected and targeted financial results, and this information may not be appropriate for other purposes.

    Non-IFRS Measures
    References are made in this press release to “operating cash flow” (OCF), “free cash flow” (FCF), “Earnings Before Interest, Tax, Depreciation and Amortization” (EBITDA), “operating costs” and “net debt”/”net cash”, which are not generally accepted accounting measures under International Financial Reporting Standards (IFRS) and do not have any standardized meaning prescribed by IFRS and, therefore, may not be comparable with similar measures presented by other public companies. Non-IFRS measures should not be considered in isolation or as a substitute for measures prepared in accordance with IFRS.

    The definition of each non-IFRS measure is presented in IPC’s MD&A (See “Non-IFRS Measures” therein).

    Operating cash flow
    The following table sets out how operating cash flow is calculated from figures shown in the Financial Statements:

      Three months ended September 30   Nine months ended September 30
    USD Thousands 2024   2023     2024   2023  
    Revenue 173,200   257,366     598,659   655,446  
    Production costs (100,984 ) (130,765 )   (328,110 ) (364,889 )
    Current tax 373   (7,459 )   (6,718 ) (16,045 )
    Operating cash flow 72,589   119,142     263,831   274,512  
                       

    The operating cash flow for the nine months ended September 30, 2023 including the operating cash flow contribution of the Brooks assets acquisition from the effective date of January 1, 2023 to the completion date of March 3, 2023 amounted to USD 279,414 thousand.

    Free cash flow
    The following table sets out how free cash flow is calculated from figures shown in the Financial Statements:

      Three months ended September 30   Nine months ended September 30
    USD Thousands 2024   2023     2024   2023  
    Operating cash flow – see above 72,589   119,142     263,831   274,512  
    Capital expenditures (99,100 ) (76,844 )   (308,457 ) (183,904 )
    Abandonment and farm-in expenditures1 (2,575 ) (2,755 )   (4,938 ) (7,683 )
    General, administration and depreciation expenses before depreciation2 (3,903 ) (3,547 )   (11,245 ) (11,124 )
    Cash financial items3 (5,280 ) (1,293 )   (13,212 ) (3,593 )
    Free cash flow (38,269 ) 34,703     (74,021 ) 68,208  

    1 See note 16 to the Financial Statements
    2 Depreciation is not specifically disclosed in the Financial Statements
    3 See notes 4 and 5 to the Financial Statements

    The free cash flow for the nine months ended September 30, 2023 including the free cash flow contribution of the Brooks assets acquisition from the effective date of January 1, 2023 to the completion date of March 3, 2023 amounted to USD 67,379 thousand.

    EBITDA
    The following table sets out the reconciliation from net result from the consolidated statement of operations to EBITDA:

      Three months ended September 30   Nine months ended September 30
    USD Thousands 2024   2023     2024   2023  
    Net result 22,875   71,681     101,804   143,269  
    Net financial items 4,124   4,257     23,942   16,227  
    Income tax 8,257   25,451     29,473   50,671  
    Depletion and decommissioning costs 30,491   31,687     96,305   71,488  
    Depreciation of other tangible fixed assets 2,023   1,509     6,503   6,503  
    Exploration and business development costs 197   (24 )   344   2,007  
    Depreciation included in general, administration and depreciation expenses 1 346   405     933   1,180  
    Sale of Assets   (11,912 )     (11,912 )
    EBITDA 68,313   123,054     259,304   279,433  

    1 Item is not shown in the Financial Statements

    The EBITDA for the nine months ended September 30, 2023 including the EBITDA contribution of the Brooks assets acquisition from the effective date of January 1, 2023 to the completion date of March 3, 2023 amounted to USD 284,334 thousand.

    Operating costs
    The following table sets out how operating costs is calculated:

      Three months ended September 30   Nine months ended September 30
    USD Thousands 2024   2023     2024   2023  
    Production costs 100,984   130,765     328,110   364,889  
    Cost of blending (29,818 ) (39,836 )   (116,699 ) (128,523 )
    Change in inventory position 2,755   (8,067 )   3,160   2,228  
    Operating costs 73,921   82,862     214,571   238,594  

    The operating costs for the nine months ended September 30, 2023 including the operating costs contribution of the Brooks assets acquisition from the effective date of January 1, 2023 to the completion date of March 3, 2023 amounted to USD 245,395 thousand.

    Net cash/(debt)
    The following table sets out how net cash/(debt) is calculated:

    USD Thousands September 30, 2024   December 31, 2023  
    Bank loans (6,431 ) (9,031 )
    Bonds1 (450,000 ) (450,000 )
    Cash and cash equivalents 299,203   517,074  
    Net cash/(debt) (157,228 ) 58,043  

    1 The bond amount represents the redeemable value at maturity (February 2027).

    Reserves and Resources Advisory
    This press release contains references to estimates of gross and net reserves and resources attributed to the Corporation’s oil and gas assets. For additional information with respect to such reserves and resources, refer to “Reserves and Resources Advisory” in the MD&A. Light, medium and heavy crude oil reserves/resources disclosed in this press release include solution gas and other by-products. Also see “Supplemental Information regarding Product Types” below.

    Reserve estimates, contingent resource estimates and estimates of future net revenue in respect of IPC’s oil and gas assets in Canada are effective as of December 31, 2023, and are included in the reports prepared by Sproule Associates Limited (Sproule), an independent qualified reserves evaluator, in accordance with National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (NI 51-101) and the Canadian Oil and Gas Evaluation Handbook (the COGE Handbook) and using Sproule’s December 31, 2023 price forecasts.

    Reserve estimates, contingent resource estimates and estimates of future net revenue in respect of IPC’s oil and gas assets in France and Malaysia are effective as of December 31, 2023, and are included in the report prepared by ERC Equipoise Ltd. (ERCE), an independent qualified reserves auditor, in accordance with NI 51-101 and the COGE Handbook, and using Sproule’s December 31, 2023 price forecasts.

    The price forecasts used in the Sproule and ERCE reports are available on the website of Sproule (sproule.com) and are contained in the AIF. These price forecasts are as at December 31, 2023 and may not be reflective of current and future forecast commodity prices.

    The reserve life index (RLI) is calculated by dividing the 2P reserves of 468 MMboe as at December 31, 2023 by the mid-point of the 2024 CMD production guidance of 46,000 to 48,000 boepd.

    IPC uses the industry-accepted standard conversion of six thousand cubic feet of natural gas to one barrel of oil (6 Mcf = 1 bbl). A BOE conversion ratio of 6:1 is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a 6:1 conversion basis may be misleading as an indication of value.

    Supplemental Information regarding Product Types

    The following table is intended to provide supplemental information about the product type composition of IPC’s net average daily production figures provided in this press release:

      Heavy Crude Oil
    (Mbopd)
    Light and Medium Crude Oil (Mbopd) Conventional Natural Gas (per day) Total
    (Mboepd)
    Three months ended        
    September 30, 2024 21.9 7.8 91.9 MMcf
    (15.3 Mboe)
    45.0
    September 30, 2023 25.8 7.1 103.4 MMcf
    (17.3 Mboe)
    50.2
    Nine months ended        
    September 30, 2024 23.7 7.9 94.8 MMcf
    (15.8 Mboe)
    47.4
    September 30, 2023 25.9 8.6 102.4 MMcf
    (17.1 Mboe)
    51.6
    Year ended        
    December 31, 2023 25.8 8.1 102.8 MMcf
    (17.1 Mboe)
    51.1
             

    This press release also makes reference to IPC’s forecast total average daily production of 46,000 to 48,000 boepd for 2024. IPC estimates that approximately 50% of that production will be comprised of heavy oil, approximately 16% will be comprised of light and medium crude oil and approximately 34% will be comprised of conventional natural gas.

    Currency
    All dollar amounts in this press release are expressed in United States dollars, except where otherwise noted. References herein to USD mean United States dollars and to MUSD mean millions of United States dollars. References herein to CAD mean Canadian dollars.

    The MIL Network

  • MIL-OSI: Valeura Energy Inc.: Completion of Internal Restructuring

    Source: GlobeNewswire (MIL-OSI)

    SINGAPORE, Nov. 05, 2024 (GLOBE NEWSWIRE) — Valeura Energy Inc. (TSX:VLE, OTCQX:VLERF) (“Valeura” or the “Company”) is pleased to announce the completion of an internal restructuring of its Thailand subsidiary companies. 

    Valeura’s working interests in all its Thai III fiscal contracts, covering the Nong Yao, Manora and Wassana fields, are now held by Valeura Energy (Thailand) Ltd, a wholly owned subsidiary of Valeura, which previously had only held an interest in the Wassana asset.  The Company anticipates that the new structure offers the potential to optimise various operational and financial aspects of these assets.  In particular, the Company anticipates realising efficiencies through ongoing contracting and procurement, as well as the pooling of future costs and historical tax loss carry-forwards associated with these assets.  As of September 30, 2024, the cumulative tax loss carry-forwards are estimated at US$397 million(1).  

    Dr. Sean Guest, President and CEO commented:

    “Today marks a milestone in delivering value for our shareholders, and completes the integration work we started after our Gulf of Thailand acquisitions in 2022 and 2023.  Early on, we identified the potential for greater efficiency by bringing our Thai III assets together through a re-organisation; our team recognised that together, these assets are worth more than the sum of their parts. 

    Pursuing this type of synergy strengthens our ability to re-invest in the business for the benefit of all stakeholders.  We intend to continue investing directly into the many organic growth opportunities inherent in our Thailand portfolio, and also seeking new ways to provide further value, including through acquisition-led growth.”

    Under Thailand’s income tax provisions, from today forward, petroleum income tax for the three subject assets will be assessed as a single entity. Tax obligations relating to the previous subsidiary company arrangement are required to be assessed immediately and settled within the next 30 days. Taxation arrangements for the Jasmine field, which is governed by a different vintage of fiscal terms (known as Thai I), and held in a separate subsidiary entity, will continue unchanged. 

    (1) Unaudited internal management estimate based on Thai baht exchange rate as of November 1, 2024, subject to review by tax advisors and auditors.

    For further information, please contact:

    Valeura Energy Inc. (General Corporate Enquiries)  +65 6373 6940
    Sean Guest, President and CEO  
    Yacine Ben-Meriem, CFO  
    Contact@valeuraenergy.com  
       
    Valeura Energy Inc. (Investor and Media Enquiries)  +1 403 975 6752 / +44 7392 940495
    Robin James Martin, Vice President, Communications and Investor Relations  
    IR@valeuraenergy.com  
       

    Contact details for the Company’s advisors, covering research analysts and joint brokers, including Auctus Advisors LLP, Canaccord Genuity Ltd (UK), Cormark Securities Inc., Research Capital Corporation, and Stifel Nicolaus Europe Limited, are listed on the Company’s website at www.valeuraenergy.com/investor-information/analysts/.

    About Valeura

    Valeura Energy Inc. is a Canadian public company engaged in the exploration, development and production of petroleum and natural gas in Thailand and in Türkiye. The Company is pursuing a growth-oriented strategy and intends to re-invest into its producing asset portfolio and to deploy resources toward further organic and inorganic growth in Southeast Asia. Valeura aspires toward value accretive growth for stakeholders while adhering to high standards of environmental, social and governance responsibility.

    Additional information relating to Valeura is also available on SEDAR+ at www.sedarplus.ca.

    Advisory and Caution Regarding Forward-Looking Information

    Certain information included in this news release constitutes forward-looking information under applicable securities legislation. Such forward-looking information is for the purpose of explaining management’s current expectations and plans relating to the future. Readers are cautioned that reliance on such information may not be appropriate for other purposes, such as making investment decisions. Forward-looking information typically contains statements with words such as “anticipate”, “believe”, “expect”, “plan”, “intend”, “estimate”, “propose”, “project”, “target” or similar words suggesting future outcomes or statements regarding an outlook. Forward-looking information in this news release includes, but is not limited to: the potential to optimise various operational and financial aspects, relating to such matters as ongoing contracting and procurement, as well as the pooling of future costs and historical tax loss carry-forwards associated with these assets and statements with respect to the growth opportunities inherent in the Company’s Thailand portfolio and the Company seeking new ways to provide further value.

    Forward-looking information is based on management’s current expectations and assumptions regarding, among other things: the ability of the Company to obtain the anticipated benefits from the internal restructuring; political stability of the areas in which the Company is operating; continued safety of operations and ability to proceed in a timely manner; continued operations of and approvals forthcoming from governments and regulators in a manner consistent with past conduct; future drilling activity on the required/expected timelines; the prospectivity of the Company’s lands; the continued favourable pricing and operating netbacks across its business; future production rates and associated operating netbacks and cash flow; decline rates; future sources of funding; future economic conditions; the impact of inflation of future costs; future currency exchange rates; interest rates; the ability to meet drilling deadlines and fulfil commitments under licences and leases; future commodity prices; the impact of the Russian invasion of Ukraine; royalty rates and taxes; future capital and other expenditures; the success obtained in drilling new wells and working over existing wellbores; the performance of wells and facilities; the availability of the required capital to funds its exploration, development and other operations, and the ability of the Company to meet its commitments and financial obligations; the ability of the Company to secure adequate processing, transportation, fractionation and storage capacity on acceptable terms; the capacity and reliability of facilities; the application of regulatory requirements respecting abandonment and reclamation; the recoverability of the Company’s reserves and contingent resources; ability to attract a partner to participate in its tight gas exploration/appraisal play in Türkiye; future growth; the sufficiency of budgeted capital expenditures in carrying out planned activities; the impact of increasing competition; the ability to efficiently integrate assets and employees acquired through acquisitions; global energy policies going forward; future debt levels; and the Company’s continued ability to obtain and retain qualified staff and equipment in a timely and cost efficient manner. In addition, the Company’s work programmes and budgets are in part based upon expected agreement among joint venture partners and associated exploration, development and marketing plans and anticipated costs and sales prices, which are subject to change based on, among other things, the actual results of drilling and related activity, availability of drilling, offshore storage and offloading facilities and other specialised oilfield equipment and service providers, changes in partners’ plans and unexpected delays and changes in market conditions. Although the Company believes the expectations and assumptions reflected in such forward-looking information are reasonable, they may prove to be incorrect.

    Forward-looking information involves significant known and unknown risks and uncertainties. Exploration, appraisal, and development of oil and natural gas reserves and resources are speculative activities and involve a degree of risk. A number of factors could cause actual results to differ materially from those anticipated by the Company including, but not limited to: the ability of management to execute its business plan or realise anticipated benefits from acquisitions; the risk of disruptions from public health emergencies and/or pandemics; competition for specialised equipment and human resources; the Company’s ability to manage growth; the Company’s ability to manage the costs related to inflation; disruption in supply chains; the risk of currency fluctuations; changes in interest rates, oil and gas prices and netbacks; potential changes in joint venture partner strategies and participation in work programmes; uncertainty regarding the contemplated timelines and costs for work programme execution; the risks of disruption to operations and access to worksites; potential changes in laws and regulations, the uncertainty regarding government and other approvals; counterparty risk; the risk that financing may not be available; risks associated with weather delays and natural disasters; and the risk associated with international activity. See the most recent annual information form and management’s discussion and analysis of the Company for a detailed discussion of the risk factors.

    The forward-looking information contained in this new release is made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless required by applicable securities laws. The forward-looking information contained in this new release is expressly qualified by this cautionary statement.

    This announcement does not constitute an offer to sell or the solicitation of an offer to buy securities in any jurisdiction, including where such offer would be unlawful. This announcement is not for distribution or release, directly or indirectly, in or into the United States, Ireland, the Republic of South Africa or Japan or any other jurisdiction in which its publication or distribution would be unlawful.

    Neither the Toronto Stock Exchange nor its Regulation Services Provider (as that term is defined in the policies of the Toronto Stock Exchange) accepts responsibility for the adequacy or accuracy of this news release.

    This information is provided by Reach, the non-regulatory press release distribution service of RNS, part of the London Stock Exchange. Terms and conditions relating to the use and distribution of this information may apply. For further information, please contact rns@lseg.com or visit www.rns.com.

    The MIL Network

  • MIL-OSI: Progress on share buyback programme

    Source: GlobeNewswire (MIL-OSI)

    Progress on share buyback programme

    ING announced today that, as part of our €2.0 billion share buyback programme announced on 31 October 2024, in total 4,016,274 shares were repurchased during the week of 31 October 2024 up to and including 1 November 2024.

    In line with the purpose of the programme to reduce the share capital of ING, the ordinary shares were repurchased at an average price of €15.64 for a total consideration of €62,798,086.93. To date approximately 3.14% of the maximum total value of the share buyback programme has been completed.

    For detailed information on the daily repurchased shares, individual share purchase transactions and weekly reports, see the ING website at www.ing.com/investorrelations.

    Note for editors

    For more on ING, please visit www.ing.com. Frequent news updates can be found in the Newsroom or via X @ING_news feed. Photos of ING operations, buildings and its executives are available for download at Flickr.

    ING PROFILE
    ING is a global financial institution with a strong European base, offering banking services through its operating company ING Bank. The purpose of ING Bank is: empowering people to stay a step ahead in life and in business. ING Bank’s more than 60,000 employees offer retail and wholesale banking services to customers in over 40 countries.

    ING Group shares are listed on the exchanges of Amsterdam (INGA NA, INGA.AS), Brussels and on the New York Stock Exchange (ADRs: ING US, ING.N).

    ING aims to put sustainability at the heart of what we do. Our policies and actions are assessed by independent research and ratings providers, which give updates on them annually. ING’s ESG rating by MSCI was reconfirmed by MSCI as ‘AA’ in August 2024 for the fifth year. As of December 2023, in Sustainalytics’ view, ING’s management of ESG material risk is ‘Strong’. Our current ESG Risk Rating, is 17.2 (Low Risk). ING Group shares are also included in major sustainability and ESG index products of leading providers. Here are some examples: Euronext, STOXX, Morningstar and FTSE Russell.

    Important legal information

    Elements of this press release contain or may contain information about ING Groep N.V. and/ or ING Bank N.V. within the meaning of Article 7(1) to (4) of EU Regulation No 596/2014 (‘Market Abuse Regulation’).

    ING Group’s annual accounts are prepared in accordance with International Financial Reporting Standards as adopted by the European Union (‘IFRS- EU’). In preparing the financial information in this document, except as described otherwise, the same accounting principles are applied as in the 2023 ING Group consolidated annual accounts. All figures in this document are unaudited. Small differences are possible in the tables due to rounding.

    Certain of the statements contained herein are not historical facts, including, without limitation, certain statements made of future expectations and other forward-looking statements that are based on management’s current views and assumptions and involve known and unknown risks and uncertainties that could cause actual results, performance or events to differ materially from those expressed or implied in such statements. Actual results, performance or events may differ materially from those in such statements due to a number of factors, including, without limitation: (1) changes in general economic conditions and customer behaviour, in particular economic conditions in ING’s core markets, including changes affecting currency exchange rates and the regional and global economic impact of the invasion of Russia into Ukraine and related international response measures (2) changes affecting interest rate levels (3) any default of a major market participant and related market disruption (4) changes in performance of financial markets, including in Europe and developing markets (5) fiscal uncertainty in Europe and the United States (6) discontinuation of or changes in ‘benchmark’ indices (7) inflation and deflation in our principal markets (8) changes in conditions in the credit and capital markets generally, including changes in borrower and counterparty creditworthiness (9) failures of banks falling under the scope of state compensation schemes (10) non-compliance with or changes in laws and regulations, including those concerning financial services, financial economic crimes and tax laws, and the interpretation and application thereof (11) geopolitical risks, political instabilities and policies and actions of governmental and regulatory authorities, including in connection with the invasion of Russia into Ukraine and the related international response measures (12) legal and regulatory risks in certain countries with less developed legal and regulatory frameworks (13) prudential supervision and regulations, including in relation to stress tests and regulatory restrictions on dividends and distributions (also among members of the group) (14) ING’s ability to meet minimum capital and other prudential regulatory requirements (15) changes in regulation of US commodities and derivatives businesses of ING and its customers (16) application of bank recovery and resolution regimes, including write down and conversion powers in relation to our securities (17) outcome of current and future litigation, enforcement proceedings, investigations or other regulatory actions, including claims by customers or stakeholders who feel misled or treated unfairly, and other conduct issues (18) changes in tax laws and regulations and risks of non-compliance or investigation in connection with tax laws, including FATCA (19) operational and IT risks, such as system disruptions or failures, breaches of security, cyber-attacks, human error, changes in operational practices or inadequate controls including in respect of third parties with which we do business and including any risks as a result of incomplete, inaccurate, or otherwise flawed outputs from the algorithms and data sets utilized in artificial intelligence (20) risks and challenges related to cybercrime including the effects of cyberattacks and changes in legislation and regulation related to cybersecurity and data privacy, including such risks and challenges as a consequence of the use of emerging technologies, such as advanced forms of artificial intelligence and quantum computing (21) changes in general competitive factors, including ability to increase or maintain market share (22) inability to protect our intellectual property and infringement claims by third parties (23) inability of counterparties to meet financial obligations or ability to enforce rights against such counterparties (24) changes in credit ratings (25) business, operational, regulatory, reputation, transition and other risks and challenges in connection with climate change and ESG-related matters, including data gathering and reporting (26) inability to attract and retain key personnel (27) future liabilities under defined benefit retirement plans (28) failure to manage business risks, including in connection with use of models, use of derivatives, or maintaining appropriate policies and guidelines (29) changes in capital and credit markets, including interbank funding, as well as customer deposits, which provide the liquidity and capital required to fund our operations, and (30) the other risks and uncertainties detailed in the most recent annual report of ING Groep N.V. (including the Risk Factors contained therein) and ING’s more recent disclosures, including press releases, which are available on www.ING.com.

    This document may contain ESG-related material that has been prepared by ING on the basis of publicly available information, internally developed data and other third-party sources believed to be reliable. ING has not sought to independently verify information obtained from public and third-party sources and makes no representations or warranties as to accuracy, completeness, reasonableness or reliability of such information.

    Materiality, as used in the context of ESG, is distinct from, and should not be confused with, such term as defined in the Market Abuse Regulation or as defined for Securities and Exchange Commission (‘SEC’) reporting purposes. Any issues identified as material for purposes of ESG in this document are therefore not necessarily material as defined in the Market Abuse Regulation or for SEC reporting purposes. In addition, there is currently no single, globally recognized set of accepted definitions in assessing whether activities are “green” or “sustainable.” Without limiting any of the statements contained herein, we make no representation or warranty as to whether any of our securities constitutes a green or sustainable security or conforms to present or future investor expectations or objectives for green or sustainable investing. For information on characteristics of a security, use of proceeds, a description of applicable project(s) and/or any other relevant information, please reference the offering documents for such security.

    This document may contain inactive textual addresses to internet websites operated by us and third parties. Reference to such websites is made for information purposes only, and information found at such websites is not incorporated by reference into this document. ING does not make any representation or warranty with respect to the accuracy or completeness of, or take any responsibility for, any information found at any websites operated by third parties. ING specifically disclaims any liability with respect to any information found at websites operated by third parties. ING cannot guarantee that websites operated by third parties remain available following the publication of this document, or that any information found at such websites will not change following the filing of this document. Many of those factors are beyond ING’s control.

    Any forward-looking statements made by or on behalf of ING speak only as of the date they are made, and ING assumes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information or for any other reason.

    This document does not constitute an offer to sell, or a solicitation of an offer to purchase, any securities in the United States or any other jurisdiction.

    Attachment

    The MIL Network

  • MIL-Evening Report: Jonathan Cook: Israel kills the journalists. Western media kills the truth of genocide in Gaza

    Report by Dr David Robie – Café Pacific.

    Western publics are being subjected to a campaign of psychological warfare, where genocide is classed as ‘self-defence’ and opposition to it ‘terrorism’. Jonathan Cook reports as the world marked the International Day to End Impunity for Crimes against Journalists at the weekend.

    ANALYSIS: By Jonathan Cook

    Israel knew that, if it could stop foreign correspondents from reporting directly from Gaza, those journalists would end up covering events in ways far more to its liking.

    They would hedge every report of a new Israeli atrocity – if they covered them at all – with a “Hamas claims” or “Gaza family members allege”. Everything would be presented in terms of conflicting narratives rather than witnessed facts. Audiences would feel uncertain, hesitant, detached.

    Israel could shroud its slaughter in a fog of confusion and disputation. The natural revulsion evoked by a genocide would be tempered and attenuated.

    For a year, the networks’ most experienced war reporters have stayed put in their hotels in Israel, watching Gaza from afar. Their human-interest stories, always at the heart of war reporting, have focused on the far more limited suffering of Israelis than the vast catastrophe unfolding for Palestinians.

    That is why Western audiences have been forced to relive a single day of horror for Israel, on October 7, 2023, as intensely as they have a year of greater horrors in Gaza — in what the World Court has judged to be a “plausible” genocide by Israel.

    That is why the media have immersed their audiences in the agonies of the families of some 250 Israelis — civilians taken hostage and soldiers taken captive — as much as they have the agonies of 2.3 million Palestinians bombed and starved to death week after week, month after month.

    That is why audiences have been subjected to gaslighting narratives that frame Gaza’s destruction as a “humanitarian crisis” rather than the canvas on which Israel is erasing all the known rules of war.

    Western media’s human-interest stories, always at the heart of war reporting, have focused on the far more limited suffering of Israelis than the vast catastrophe unfolding for Palestinians. Image: www.jonathan-cook.net

    While foreign correspondents sit obediently in their hotel rooms, Palestinian journalists have been picked off one by one — in the greatest massacre of journalists in history.

    Israel is now repeating that process in Lebanon. On the night of October 24, it struck a residence in south Lebanon where three journalists were staying. All were killed.

    In an indication of how deliberate and cynical Israel’s actions are, it put its military’s crosshairs on six Al Jazeera reporters last month, smearing them as “terrorists” working for Hamas and Islamic Jihad. They are reportedly the last surviving Palestinian journalists in northern Gaza, which Israel has sealed off while it carries out the so-called “General’s Plan”.

    Israel wants no one reporting its final push to ethnically cleanse northern Gaza by starving out the 400,000 Palestinians still there and executing anyone who remains as a “terrorist”.

    These six join a long list of professionals defamed by Israel in the interests of advancing its genocide — from doctors and aid workers to UN peacekeepers.

    Sympathy for Israel
    Perhaps the nadir of Israel’s domestication of foreign journalists was reached last month in a report by CNN. Back in February whistleblowing staff there revealed that the network’s executives have been actively obscuring Israeli atrocities to portray Israel in a more sympathetic light.

    In a story whose framing should have been unthinkable — but sadly was all too predictable — CNN reported on the psychological trauma some Israeli soldiers are suffering from time spent in Gaza, in some cases leading to suicide.

    Committing a genocide can be bad for your mental health, it seems. Or as CNN explained, its interviews “provide a window into the psychological burden that the war is casting on Israeli society”.

    In its lengthy piece, titled “He got out of Gaza, but Gaza did not get out of him”, the atrocities the soldiers admit committing are little more than the backdrop as CNN finds yet another angle on Israeli suffering. Israeli soldiers are the real victims — even as they perpetrate a genocide on the Palestinian people.

    One bulldozer driver, Guy Zaken, told CNN he could not sleep and had become vegetarian because of the “very, very difficult things” he had seen and had to do in Gaza.

    What things? Zaken had earlier told a hearing of the Israeli Parliament that his unit’s job was to drive over many hundreds of Palestinians, some of them alive.

    CNN reported: “Zaken says he can no longer eat meat, as it reminds him of the gruesome scenes he witnessed from his bulldozer in Gaza.”

    Doubtless some Nazi concentration camp guards committed suicide in the 1940s after witnessing the horrors there — because they were responsible for them. Only in some weird parallel news universe, would their “psychological burden” be the story.

    After a huge online backlash, CNN amended an editor’s note at the start of the article that originally read: “This story includes details about suicide that some readers may find upsetting.”

    Readers, it was assumed, would find the suicide of Israeli soldiers upsetting, but apparently not the revelation that those soldiers were routinely driving over Palestinians so that, as Zaken explained, “everything squirts out”.

    Banned from Gaza
    Finally, a year into Israel’s genocidal war, now rapidly spreading into Lebanon, some voices are being raised very belatedly to demand the entry of foreign journalists into Gaza.

    This week — in a move presumably designed, as November’s elections loom, to ingratiate themselves with voters angry at the party’s complicity in genocide — dozens of Democratic members of the US Congress wrote to President Joe Biden asking him to pressure Israel to give journalists “unimpeded access” to the enclave.

    Don’t hold your breath.

    Western media have done very little themselves to protest their exclusion from Gaza over the past year — for a number of reasons.

    Given the utterly indiscriminate nature of Israel’s bombardment, major outlets have not wanted their journalists getting hit by a 2000lb bomb for being in the wrong place.

    That may in part be out of concern for their welfare. But there are likely to be more cynical concerns.

    Having foreign journalists in Gaza blown up or executed by snipers would drag media organisations into direct confrontation with Israel and its well-oiled lobby machine.

    The response would be entirely predictable, insinuating that the journalists died because they were colluding with “the terrorists” or that they were being used as “human shields” — the excuse Israel has rolled out time and again to justify its targeting of doctors in Gaza and UN peacekeepers in Lebanon.

    But there’s a bigger problem. The establishment media have not wanted to be in a position where their journalists are so close to the “action” that they are in danger of providing a clearer picture of Israel’s war crimes and its genocide.

    The media’s current distance from the crime scene offers them plausible deniability as they both-sides every Israeli atrocity.

    In previous conflicts, western reporters have served as witnesses, assisting in the prosecution of foreign leaders for war crimes. That happened in the wars that attended the break-up of Yugoslavia, and will doubtless happen once again if Russian President Valdimir Putin is ever delivered to The Hague.

    But those journalistic testimonies were harnessed to put the West’s enemies behind bars, not its closest ally.

    The media do not want their reporters to become chief witnesses for the prosecution in the future trials of Israeli Prime Minister Benjamin Netanyahu and his Defence Minister, Yoav Gallant, at the International Criminal Court. The ICC’s Prosecutor, Karim Khan, is seeking arrest warrants for them both.

    After all, any such testimony from journalists would not stop at Israel’s door. They would implicate Western capitals too, and put establishment media organisations on a collision course with their own governments.

    The Western media does not see its job as holding power to account when the West is the one committing the crimes.

    Censoring Palestinians
    Journalist whistleblowers have gradually been coming forward to explain how establishment news organisations — including the BBC and the supposedly liberal Guardian — are sidelining Palestinian voices and minimising the genocide.

    An investigation by Novara Media recently revealed mounting unhappiness in parts of The Guardian newsroom at its double standards on Israel and Palestine.

    Its editors recently censored a commentary by preeminent Palestinian author Susan Abulhawa after she insisted on being allowed to refer to the slaughter in Gaza as “the holocaust of our times”.

    Senior Guardian columnists such as Jonathan Freedland made much during Jeremy Corbyn’s tenure as leader of the Labour party that Jews, and Jews alone, had the right to define and name their own oppression.

    That right, however, does not appear to extend to Palestinians.

    As staff who spoke to Novara noted, The Guardian’s Sunday sister paper, The Observer, had no problem opening its pages to British Jewish writer Howard Jacobson to smear as a “blood libel” any reporting of the provable fact that Israel has killed many, many thousands of Palestinian children in Gaza.

    One veteran journalist there said: “Is The Guardian more worried about the reaction to what is said about Israel than Palestine? Absolutely.”

    Another staff member admitted it would be inconceivable for the paper to be seen censoring a Jewish writer. But censoring a Palestinian one is fine, it seems.

    Other journalists report being under “suffocating control” from senior editors, and say this pressure exists “only if you’re publishing something critical of Israel”.

    According to staff there, the word “genocide” is all but banned in the paper except in coverage of the International Court of Justice, whose judges ruled nine months ago that a “plausible” case had been made that Israel was committing genocide. Things have got far worse since.

    Whistleblowing journalists
    Similarly, “Sara”, a whistleblower who recently resigned from the BBC newsroom and spoke of her experiences to Al Jazeera’s Listening Post, said Palestinians and their supporters were routinely kept off air or subjected to humiliating and insensitive lines of questioning.

    Some producers have reportedly grown increasingly reluctant to bring on air vulnerable Palestinians, some of whom have lost family members in Gaza, because of concerns about the effect on their mental health from the aggressive interrogations they were being subjected to from anchors.

    According to Sara, BBC vetting of potential guests overwhelmingly targets Palestinians, as well as those sympathetic to their cause and human rights organisations. Background checks are rarely done of Israelis or Jewish guests.

    She added that a search showing that a guest had used the word “Zionism” — Israel’s state ideology — in a social media post could be enough to get them disqualified from a programme.

    Even officials from one of the biggest rights group in the world, the New York-based Human Rights Watch, became persona non grata at the BBC for their criticisms of Israel, even though the corporation had previously relied on their reports in covering Ukraine and other global conflicts.

    Israeli guests, by contrast, “were given free rein to say whatever they wanted with very little pushback”, including lies about Hamas burning or beheading babies and committing mass rape.

    An email cited by Al Jazeera from more than 20 BBC journalists sent last February to Tim Davie, the BBC’s director-general, warned that the corporation’s coverage risked “aiding and abetting genocide through story suppression”.

    Upside-down values
    These biases have been only too evident in the BBC’s coverage, first of Gaza and now, as media interest wanes in the genocide, of Lebanon.

    Headlines — the mood music of journalism, and the only part of a story many of the audience read — have been uniformly dire.

    For example, Netanyahu’s threats of a Gaza-style genocide against the Lebanese people last month if they did not overthrow their leaders were soft-soaped by the BBC headline: “Netanyahu’s appeal to Lebanese people falls on deaf ears in Beirut.”

    Reasonable readers would have wrongly inferred both that Netanyahu was trying to do the Lebanese people a favour (by preparing to murder them), and that they were being ungrateful in not taking up his offer.

    It has been the same story everywhere in the establishment media. In another extraordinary, revealing moment, Kay Burley of Sky News announced last month the deaths of four Israeli soldiers from a Hezbollah drone strike on a military base inside Israel.

    With a solemnity usually reserved for the passing of a member of the British royal family, she slowly named the four soldiers, with a photo of each shown on screen. She stressed twice that all four were only 19 years old.

    Sky News seemed not to understand that these were not British soldiers, and that there was no reason for a British audience to be especially disturbed by their deaths. Soldiers are killed in wars all the time — it is an occupational hazard.

    And further, if Israel considered them old enough to fight in Gaza and Lebanon, then they were old enough to die too without their age being treated as particularly noteworthy.

    But more significantly still, Israel’s Golani Brigade to which these soldiers belonged has been centrally involved in the slaughter of Palestinians over the past year. Its troops have been responsible for many of the tens of thousands of children killed and maimed in Gaza.

    Each of the four soldiers was far, far less deserving of Burley’s sympathy and concern than the thousands of children who have been slaughtered at the hands of their brigade. Those children are almost never named and their pictures are rarely shown, not least because their injuries are usually too horrifying to be seen.

    It was yet more evidence of the upside-down world the establishment media has been trying to normalise for its audiences.

    It is why statistics from the United States, where the coverage of Gaza and Lebanon may be even more unhinged, show faith in the media is at rock bottom. Fewer than one in three respondents — 31 percent — said they still had a “great deal or fair amount of trust in mass media”.

    Crushing dissent
    Israel is the one dictating the coverage of its genocide. First by murdering the Palestinian journalists reporting it on the ground, and then by making sure house-trained foreign correspondents stay well clear of the slaughter, out of harm’s way in Tel Aviv and Jerusalem.

    And as ever, Israel has been able to rely on the complicity of its Western patrons in crushing dissent at home.

    Last week, a British investigative journalist, Asa Winstanley, an outspoken critic of Israel and its lobbyists in the UK, had his home in London raided at dawn by counter-terrorism police.

    Though the police have not arrested or charged him — at least not yet — they snatched his electronic devices. He was warned that he is being investigated for “encouragement of terrorism” in his social media posts.

    Police told Middle East Eye that his devices had been seized as part of an investigation into suspected terrorism offences of “support for a proscribed organisation” and “dissemination of terrorist documents”.

    The police can act only because of Britain’s draconian, anti-speech Terrorism Act.

    Section 12, for example, makes the expression of an opinion that could be interpreted as sympathetic to armed Palestinian resistance to Israel’s illegal occupation — a right enshrined in international law but sweepingly dismissed as “terrorism” in the West — itself a terrorism offence.

    Those journalists who haven’t been house-trained in the establishment media, as well as solidarity activists, must now chart a treacherous path across intentionally ill-defined legal terrain when talking about Israel’s genocide in Gaza.

    Winstanley is not the first journalist to be accused of falling foul of the Terrorism Act. In recent weeks, Richard Medhurst, a freelance journalist, was arrested at Heathrow airport on his return from a trip abroad. Another journalist-activist, Sarah Wilkinson, was briefly arrested after her home was ransacked by police.

    Their electronic devices were seized too.

    Meanwhile, Richard Barnard, co-founder of Palestine Action, which seeks to disrupt the UK’s supply of weapons to Israel’s genocide, has been charged over speeches he has made against the genocide.

    It now appears that all these actions are part of a specific police campaign targeting journalists and Palestinian solidarity activists: “Operation Incessantness”.

    The message this clumsy title is presumably supposed to convey is that the British state is coming after anyone who speaks out too loudly against the British government’s continuing arming and complicity in Israel’s genocide.

    Notably, the establishment media have failed to cover this latest assault on journalism and the role of a free press — supposedly the very things they are there to protect.

    The raid on Winstanley’s home and the arrests are intended to intimidate others, including independent journalists, into silence for fear of the consequences of speaking up.

    This has nothing to do with terrorism. Rather, it is terrorism by the British state.

    Once again the world is being turned upside down.

    Echoes from history
    The West is waging a campaign of psychological warfare on its populations: it is gaslighting and disorientating them, classing genocide as “self-defence” and opposition to it a form of “terrorism”.

    This is an expansion of the persecution suffered by Julian Assange, the Wikileaks founder who spent years locked up in London’s Belmarsh high-security prison.

    His unprecedented journalism — revealing the darkest secrets of Western states — was redefined as espionage. His “offence” was revealing that Britain and the US had committed systematic war crimes in Iraq and Afghanistan.

    Now, on the back of that precedent, the British state is coming after journalists simply for embarrassing it.

    Late last month I attended a meeting in Bristol against the genocide in Gaza at which the main speaker was physically absent after the British state failed to issue him an entry visa.

    The missing guest — he had to join us by zoom — was Mandla Mandela, the grandson of Nelson Mandela, who was locked up for decades as a terrorist before becoming the first leader of post-apartheid South Africa and a feted, international statesman.

    Mandla Mandela was until recently a member of the South African Parliament.

    A Home Office spokesperson told Middle East Eye that the UK only issued visas “to those who we want to welcome to our country”.

    Media reports suggest Britain was determined to exclude Mandela because, like his grandfather, he views the Palestinian struggle against Israeli apartheid as intimately linked to the earlier struggle against South Africa’s apartheid.

    The echoes from history are apparently entirely lost on officials: the UK is once again associating the Mandela family with terrorism. Before it was to protect South Africa’s apartheid regime. Now it is to protect Israel’s even worse apartheid and genocidal regime.

    The world is indeed turned on its head. And the West’s supposedly “free media” is playing a critical role in trying to make our upside-down world seem normal.

    That can only be achieved by failing to report the Gaza genocide as a genocide. Instead, Western journalists are serving as little more than stenographers. Their job: to take dictation from Israel.

    Jonathan Cook is an award-winning British journalist. He was based in Nazareth, Israel, for 20 years and returned to the UK in 2021. He is the author of three books on the Israel-Palestine conflict, including Disappearing Palestine: Israel’s Experiments in Human Despair (2008). In 2011, Cook was awarded the Martha Gellhorn Special Prize for Journalism for his work on Palestine and Israel. This article was first published in Middle East Eye and is republished with the author’s permission.

    This article was first published on Café Pacific.

    MIL OSI AnalysisEveningReport.nz

  • MIL-OSI Europe: Written question – Cooperation with EUROGENDFOR – P-002299/2024

    Source: European Parliament

    29.10.2024

    Priority question for written answer  P-002299/2024/rev.1
    to the Council
    Rule 144
    Özlem Demirel (The Left)

    The European Gendarmerie Force (EUROGENDFOR) is an association comprising a number of European countries that have police forces with a ‘robust mandate’. Those forces can be deployed in war zones under the command of the military.

    • 1.What plans do the Council and its relevant working groups have to bring about closer cooperation with EUROGENDFOR? How will those plans be put into practice?
    • 2.What role could a liaison officer play, and where would such an officer be based?
    • 3.Does the Council believe that EUROGENDFOR could also be used in the context of EU measures in Ukraine, Moldova or Israeli-occupied Gaza, and in the Council’s view, which of those countries could be granted observer status in EUROGENDFOR?

    Submitted: 29.10.2024

    Last updated: 4 November 2024

    MIL OSI Europe News

  • MIL-OSI Europe: Briefing – Performance-based delivery of the Recovery and Resilience Facility: Blueprint for future EU spending instruments? – 04-11-2024

    Source: European Parliament

    The European Union (EU) is committed to ensuring its budget delivers maximum value for citizens by focusing on results and performance. In 2018, as part of the shift towards performance-based budgeting, the EU revised the rules applicable to the general budget and introduced the possibility of financing that is not linked to cost (FNLC) in addition to the traditional ways of financing based on incurred costs (Article 125 of EU Regulation 2018/1046). Under this method, payments are based on results achieved, and are made if a beneficiary fulfils predefined conditions linked to progress in implementing or achieving the objectives of a project or programme. The Recovery and Resilience Facility (RRF) – the EU’s ground-breaking instrument created to support the Member States’ post-pandemic economic recovery – is a key example of how this delivery method is applied. For the first time, disbursements to the Member States depend on achieving pre-defined milestones and targets relating to the implementation of reform and investment measures. Since the creation of the RRF, the EU has set up similar instruments in other policy areas. The Ukraine Facility (UF) and the Reform and Growth Facility for the Western Balkans (WBF), both launched in 2024, share some key features with the RRF delivery method. Along with the application of the FNLC principle for payments, other common features include the prominent role of the reform measures, using scoreboards to monitor implementation, and setting up special forums, known as ‘dialogues’, for the exchange of information and views with the European Parliament. Examining in detail this innovative way of funding as it applies to the three facilities helps to shed light on an emerging, performance-based modus operandi that is already being discussed as a possible blueprint for other spending tools under the post-2027 EU budget.

    MIL OSI Europe News

  • MIL-OSI: Gran Tierra Energy Inc. Reports Third Quarter 2024 Results and Announces its Sixth Consecutive Ecuador Oil Discovery from the Charapa-B7 Well

    Source: GlobeNewswire (MIL-OSI)

    • Gran Tierra Announces its Sixth Consecutive Ecuador Oil Discovery from the Charapa-B7 Well and Has Achieved Cumulative Production of Over 1 Million Barrels of Oil in Ecuador
    • Gran Tierra Achieved $1 Million in Net Income and Generated $60 Million in Funds Flow from Operations(2), an Increase of 31% from Prior Quarter
    • Third Quarter 2024 Total Average WI Production of 32,764 BOPD
    • Operating Netback of $101 Million and Adjusted EBITDA of $93 Million(1)(4)
    • Exited the Quarter with $278 Million in Cash
    • Entered into new credit facility for further liquidity which is currently undrawn

    CALGARY, Alberta, Nov. 04, 2024 (GLOBE NEWSWIRE) — Gran Tierra Energy Inc. (“Gran Tierra” or the “Company”) (NYSE American:GTE) (TSX:GTE) (LSE:GTE) announced the Company’s financial and operating results for the quarter ended September 30, 2024 (“the Quarter”). All dollar amounts are in United States dollars, and production amounts are on an average working interest (“WI”) before royalties basis unless otherwise indicated. Per barrel (“bbl”) and bbl per day (“BOPD”) amounts are based on WI sales before royalties. For per bbl amounts based on net after royalty (“NAR”) production, see Gran Tierra’s Quarterly Report on Form 10-Q filed November 4, 2024.

    Message to Shareholders

    “On October 31, 2024 we were excited to have announced the close of our acquisition of i3 Energy plc (“i3 Energy”). We believe the purchase of i3 Energy uniquely positions Gran Tierra as a premier diversified oil and gas company with assets in Canada, Colombia, and Ecuador. The i3 Energy acquisition has diversified Gran Tierra into Canada and has added 253 net booked drilling locations(1), 77% operated production totaling approximately 18,000 bbls of oil equivalent per day, almost 1.2 million acres (0.6 million acres net) including 53 gross sections in the Montney and 144 gross sections in the Clearwater, two of the most prolific plays in North America. The i3 Energy acquisition has increased Gran Tierra’s PDP reserves(1) by 42 million bbls of oil equivalent (“MMBOE”) or 96%, 1P(1) by 88 MMBOE an increase of 97%, and 2P(1) by 174 MMBOE an increase of 119%. We believe the currently depressed natural gas pricing we see in Western Canada will be alleviated as major Liquified Natural Gas projects including LNG Canada are brought online. In the short term, Gran Tierra will focus on developing the significant oil weighted assets in its Canadian and South American portfolio.

    We would like to take this opportunity to welcome our new shareholders in Gran Tierra and look forward to engaging with, and updating them on the Company’s strategy in the coming months. We look forward to the integration of our teams and are confident the combined company will have top tier technical and operational skill sets across a broad portfolio. We are eager to implement industry leading technology currently used in Canada in both our Ecuador and Colombia operations, and are equally looking forward to bringing our reservoir modeling, exploration knowledge and asset management expertise into Canada. Combined we are a much stronger company.

    Additionally, having our six consecutive discovery in Ecuador and reaching the milestone of 1 million cumulative bbls of oil produced from our operations in Ecuador is a significant achievement for Gran Tierra, highlighting our strong presence and success in the region. The productivity of the Ecuador wells is a testament to the geology in the Oriente and Putumayo Basins, and underpins a key pillar of growth going forward. We remain excited about the potential of the Arawana-Bocachico play, and the two remaining Zabaleta wells to be drilled by the end of the year that will provide essential insights into the size and scope of this promising opportunity”, commented Gary Guidry, President and Chief Executive Officer of Gran Tierra.

    Operational Update:

    • Acquisition of i3 Energy
      • On October 31, 2024, Gran Tierra completed its acquisition of i3 Energy. Gran Tierra is integrating the Canadian operations and are forecasting an active Q4 2024, including drilling 19 gross wells (8.4 net), targeting each of its core operating areas in Central AB, Simonette, Clearwater and Wapiti.
      • The Company drilled 2 gross (2 net) horizontal Dunvegan oil wells at Simonette. These high-impact 2-mile wells are currently being stimulated and are expected to be brought on stream in late November. With success, Gran Tierra can drill 2 additional Dunvegan development wells in 2025.
      • Clearwater activity commenced in mid-October with the Company’s first operated Clearwater multilateral well at Dawson (100% working interest). The 8-leg multilateral horizontal well (11,870 m of total lateral length) was a follow-up to the Company’s initial 6-leg (7,500 m of total lateral length) discovery at Dawson. The 8-leg well follow-up multilateral was located structurally up-dip of the discovery well and encountered high quality reservoir throughout while drilling. The well will be placed on production imminently as the rig has skidded to and spud the third Clearwater well from the same pad. The Company has been working to secure multiple pad sites at East Dawson to facilitate future expansion of the field, upon further operational success. Following these two wells the rig will move to Walrus and drill 2 prospective Falher sands.
      • In addition to the operated capital program, Gran Tierra plans to participate in 10 gross (1.67 net) non-operated partner horizontal wells across its land base.
      • In connection with i3 Energy acquisition closing on October 31, 2024, the Company amended and restated the existing revolving credit facility agreement of i3 Energy Canada Ltd. (“i3 Energy Canada”) with National Bank of Canada dated March 22, 2024. As a result of the amendment and restatement, among other things, the borrowing base was revised to C$100.0 million (US$74.1 million) with available commitment of a C$50.0 million (US$37.0 million) revolving credit facility comprised of C$35.0 million (US$25.9 million) syndicated facility and C$15.0 million (US$11.1 million) of operating facility. Subject to the next borrowing base redetermination which will occur on or before June 30, 2025, the revolving credit facility is available until October 31, 2025 with a repayment date of October 31, 2026, which may be extended by further periods of up to 364 days, subject to lender approval. The facility is undrawn.
    • Exploration
      • Gran Tierra has successfully drilled its sixth consecutive oil discovery in Ecuador, the Charapa-B7 well. The wells drilled in Ecuador continue to yield strong results producing over 1 million cumulative bbls of oil to date which highlights the exceptional potential of the Oriente and Putumayo basins.
    Well Zone Onstream
    Date
    IP30
    (BOPD)
    1
    IP90
    (BOPD)
    2
    IP30
    BS&W
    3
    API GOR
    (scf/stb)
    4
    Cumulative
    Production to
    Date (Mbbl)
    5
    Charapa-B5 Hollin 11/9/2022 1,092 910 2% 28 160 307
    Bocachico-J1 Basal Tena 5/30/2023 1,296 1,146 <1% 20 204 449
    Arawana-J1 Basal Tena 5/17/2024 1,182 970 <1% 20 264 131
    Bocachico Norte-J1 T-Sand 8/1/2024 833 519 3% 35 361 47
    Charapa-B6 Hollin 8/7/2024 1,645 21% 28 49 77
    Charapa-B7 Basal Tena 8/30/2024 2,043 <1% 25 153 112

        1. Average initial 30-day production per well.
        2. Average initial 90-day production per well.
        3. Percentage of basic sediment and water in the initial 30-day production.
        4. Gas-oil ratio and standard cubic feet per stock tank barrel.
        5. Thousand bbls of oil and based on production up to November 1, 2024.

    • The drilling rig has been moved from the Charapa Block and mobilized to the Chanangue Block to drill two wells – the Zabaleta-K1 and Zabaleta Oeste-K1 exploration wells. The Zabaleta-K1 well is located four kilometers (“km”) to the east of the Arawana-J1 well drilled earlier this year and is 200 feet up structure. The well spud on October 22 2024, and we have currently drilled to 9,488 feet. Both wells will target the Basal Tena formation as well as assess potential in the T-Sand, U-Sand and B-Limestone.
    • During the Quarter, the 238 km2 3D seismic program of the Charapa Block was completed, the data has been processed and is currently being interpreted. Preliminary interpretations of the high-quality 3D data confirm potential prospectivity and additional areas of interest identified on seismic, including better definition over the Charapa structure. The 3D data will further delineate reserves, underpin future drilling locations scheduled for 2025 and support future development planning.
    • Development
      • The planning, civil works, and facility construction at Cohembi in the Suroriente Block are progressing, paving the way for drilling operations to commence in late Q4 2024.
      • Acordionero water treatment facilities expansion is expected to be completed mid-December which will result in an addition of 21,500 bbls of water handling per day which represents a 35% increase in water treatment capacity. This will allow for further well optimizations to increase injection and associated oil production. Gran Tierra continues to steadily increased total fluid production and water injection by ~18% per year to continue growing and maintaining oil production while improving sweep efficiencies and recoveries.

    Key Highlights of the Quarter:

    • Production: Gran Tierra’s total average WI production, which is before the i3 acquisition that has an effective date of October 31, 2024, was 32,764 BOPD, which was consistent with the second quarter 2024 (“the Prior Quarter”). During the Quarter the Company had lower volumes in the Acordionero field caused by downtime related to workovers, partially offset by higher production in the Costayaco field in Colombia, and increased production from the Chanangue and Charapa Blocks in Ecuador as a result of a successful exploration drilling campaign.
    • Net Income: Gran Tierra incurred net income of $1 million, compared to a net income of $36.4 million in the Prior Quarter and a net income of $7 million in the third quarter of 2023.
    • Adjusted EBITDA(2): Adjusted EBITDA(2) was $93 million compared to $103 million in the Prior Quarter and $119 million in the third quarter of 2023. Twelve month trailing Net Debt(2) to Adjusted EBITDA(2) was 1.3 times and the Company continues to have a long term target of 1.0 times.
    • Funds Flow from Operations(2): Funds flow from operations(2) was $60 million ($1.96 per share), up 31% from the Prior Quarter and down 24% from the third quarter of 2023.
    • Cash and Debt: As of September 30, 2024, the Company had a cash balance of $278 million, total debt of $787 million and net debt(2) of $509 million. During the Quarter, the Company issued additional $150 million of 9.50% Senior Notes due October 2029 and received cash proceeds of $140 million. Of the total amount of proceeds received, $100 million has been used for financing the purchase price and transaction costs related to the i3 Energy acquisition with the remainder to be used for general corporate purposes.
    • Share Buybacks: As a result of the i3 Energy acquisition announced on August 19, 2024, Gran Tierra was required to pause its share buyback program resulting in only 371,130 shares repurchased during the Quarter. From January 1, 2023 to September 30, 2024, the Company repurchased approximately 4.0 million shares, or 12% of shares issued and outstanding at January 1, 2023, from free cash flow(2).
    • Return on Average Capital Employed(2): The Company achieved return on average capital employed(2) of 17% during the Quarter and 16% over the trailing 12 months.

    Additional Key Financial Metrics:

    • Capital Expenditures: Capital expenditures of $53 million were lower than the $61 million in the Prior Quarter due to only operating one drilling rig during the Quarter compared to two in the Prior Quarter. Capital expenditures were up from $43 million compared to the third quarter of 2023 as a result of a more active exploration program in the Quarter when compared to the third quarter of 2023.
    • Oil Sales: Gran Tierra generated oil sales of $151 million, down 16% from the third quarter of 2023 as a result of weaker Brent pricing, higher Castilla, Vasconia and Oriente oil differentials and 4% lower sales volumes as a result of lower production. Oil sales decreased 9% from the Prior Quarter primarily due to a 7% decrease in Brent price and higher Castilla, Oriente, and Vasconia oil differentials offset by 1% higher sales volumes.
    • Quality and Transportation Discounts: The Company’s quality and transportation discounts per bbl were higher during the Quarter at $14.10, compared to $12.79 in the Prior Quarter and $11.83 in the third quarter of 2023. The Castilla oil differential per bbl widened to $8.83 from $8.21 in the Prior Quarter and from $6.64 in the third quarter of 2023 (Castilla is the benchmark for the Company’s Middle Magdalena Valley Basin oil production). The Vasconia differential per bbl widened to $5.07 from $4.00 in the Prior Quarter, and from $3.59 in the third quarter of 2023. Finally, the Ecuadorian benchmark, Oriente, per bbl was $9.15, up from $8.38 in the Prior Quarter, and up from $7.69 one year ago. The current(3) Castilla differential is approximately $8.50 per bbl, the Vasconia differential is approximately $5.00 per bbl and the Oriente differential is approximately $9.20 per bbl.
    • Operating Expenses: Gran Tierra’s operating expenses decreased by 2% to $46 million, compared to the Prior Quarter primarily due to lower workover costs, offset by higher lifting costs primarily associated with inventory fluctuations in Ecuador. Compared to the third quarter of 2023, operating expenses decreased by 7% from $49 million, primarily due to lower lifting costs associated with power generation, equipment rental and road maintenance, partially offset by higher workover activities. On a per bbl basis, operating expense decreased by 2% when compared to the third quarter of 2023 and decreased by 4% when compared to the Prior Quarter.
    • Transportation Expenses: The Company’s transportation expenses decreased by 31% to $4 million, compared to the Prior Quarter of $6 million and increased by 2% from the third quarter of 2023. Transportation expenses were higher than the same period in 2023 as a result of increases in trucking tariffs for Acordionero volumes and higher sales volumes transported in Ecuador during the Quarter. Transportation expenses, when compared to the Prior Quarter, were lower due to the utilization of shorter distance delivery points in the Quarter.
    • Operating Netback(2)(4): The Company’s operating netback(2)(4) was $34.18 per bbl, down 12% from the Prior Quarter and down 16% from the third quarter of 2023 commensurate with the decrease in Brent Price and higher differentials.
    • General and Administrative (“G&A”) Expenses: G&A expenses before stock-based compensation were $3.20 per bbl, down from $3.77 per bbl in the Prior Quarter due to lower consulting, business development and travel expenses and up from $2.68 per bbl, when compared to the third quarter of 2023.
    • Cash Netback(2): Cash netback(2) per bbl was $20.34, compared to $15.85 in the Prior Quarter primarily as a result of lower current tax expenses of $5.13 per bbl compared to a current tax expense of $14.54 per bbl in the Prior Quarter as a result of a one time tax adjustment incurred in the Prior Quarter. Compared to one year ago, cash netback(2) per bbl decreased by $5.14 from $25.48 per bbl as a result of lower operating netback primarily due to lower Brent pricing and higher differentials.

    Financial and Operational Highlights (all amounts in $000s, except per share and bbl amounts)

      Three Months Ended
    September 30,
      Three
    Months
    Ended
    June 30,
      Nine Months Ended
    September 30,
      2024 2023   2024   2024 2023
                   
    Net Income (Loss) $1,133 $6,527   $36,371   $37,426 $(13,998)
    Per Share – Basic and Diluted(5) $0.04 $0.20   $1.16   $1.20 $(0.42)
                   
    Oil Sales $151,373 $179,921   $165,609   $474,559 $482,013
    Operating Expenses (46,060) (49,367)   (47,035)   (141,561) (139,227)
    Transportation Expenses (3,911) (3,842)   (5,690)   (14,185) (10,599)
    Operating Netback(2)(4) $101,402 $126,712   $112,884   $318,813 $332,187
                   
    G&A Expenses Before Stock-Based Compensation $9,491 $8,307   $10,967   $31,240 $29,052
    G&A Stock-Based Compensation (Recovery) Expense (3,145) 1,931   6,160   6,376 3,748
    G&A Expenses, Including Stock Based Compensation $6,346 $10,238   $17,127   $37,616 $32,800
                   
    Adjusted EBITDA(2) $92,794 $119,235   $103,004   $290,590 $306,391
                   
    EBITDA(2) $97,365 $115,382   $101,187   $290,443 $294,391
                   
    Net Cash Provided by Operating Activities $78,654 $70,381   $73,233   $212,714 $157,511
                   
    Funds Flow from Operations(2) $60,338 $79,000   $46,167   $180,812 $192,122
                   
    Capital Expenditures $52,921 $43,080   $61,273   $169,525 $179,707
                   
    Free Cash Flow(2) $7,417 $35,920   $(15,106)   $11,287 $12,415
                   
    Average Daily Volumes (BOPD)              
    WI Production Before Royalties 32,764 33,940   32,776   32,595 33,098
    Royalties (6,776) (7,164)   (6,774)   (6,650) (6,592)
    Production NAR 25,988 26,776   26,002   25,945 26,506
    (Increase) Decrease in Inventory (524) (380)   (811)   (367) (222)
    Sales 25,464 26,396   25,191   25,578 26,284
    Royalties, % of WI Production Before Royalties 21% 21%   21%   20% 20%
                   
    Per bbl              
    Brent $78.71 $85.92   $85.03   $81.82 $81.94
    Quality and Transportation Discount (14.10) (11.83)   (12.79)   (14.11) (14.76)
    Royalties (13.58) (16.06)   (15.31)   (13.97) (13.58)
    Average Realized Price 51.03 58.03   56.93   53.74 53.60
    Transportation Expenses (1.32) (1.24)   (1.96)   (1.61) (1.18)
    Average Realized Price Net of Transportation Expenses 49.71 56.79   54.97   52.13 52.42
    Operating Expenses (15.53) (15.92)   (16.17)   (16.03) (15.48)
    Operating Netback(2)(4) 34.18 40.87   38.80   36.10 36.94
    G&A Expenses Before Stock-Based Compensation (3.20) (2.68)   (3.77)   (3.54) (3.23)
    Transaction Costs (0.49)     (0.17)
    Realized Foreign Exchange Gain (Loss) 0.34 (0.64)   0.37   0.07 (1.77)
    Interest Expense, Excluding Amortization of Debt Issuance Costs (5.66) (3.84)   (5.38)   (5.38) (3.85)
    Interest Income 0.23 0.09   0.35   0.27 0.19
    Net Lease Payments 0.07 0.18   0.02   0.07 0.17
    Current Income Tax Expense (5.13) (8.50)   (14.54)   (6.96) (7.08)
    Cash Netback(2) $20.34 $25.48   $15.85   $20.46 $21.37
                   
    Share Information (000s)              
    Common Stock Outstanding, End of Period(5) 30,651 33,288   31,022   30,651 33,288
    Weighted Average Number of Shares of Common Stock Outstanding – Basic(5) 30,733 33,287   31,282   31,274 33,675
    Weighted Average Number of Shares of Common Stock Outstanding – Diluted(5) 30,733 33,350   31,282   31,274 33,675

    (1) Based on the i3 Energy GLJ Report report dated July 31, 2024. See “Presentation of Oil and Gas Information”.
    (2) Funds flow from operations, operating netback, net debt, cash netback, return on average capital employed, earnings before interest, taxes and depletion, depreciation and accretion (“DD&A”) (EBITDA) and EBITDA adjusted for non-cash lease expense, lease payments, foreign exchange gains or losses, stock-based compensation expense, other gains or losses, transaction costs and financial instruments gains or losses (“Adjusted EBITDA”), cash flow and free cash flow are non-GAAP measures and do not have standardized meanings under generally accepted accounting principles in the United States of America (“GAAP”). Cash flow refers to funds flow from operations. Free cash flow refers to funds flow from operations less capital expenditures. Refer to “Non-GAAP Measures” in this press release for descriptions of these non-GAAP measures and, where applicable, reconciliations to the most directly comparable measures calculated and presented in accordance with GAAP.
    (3) Gran Tierra’s fourth quarter-to-date 2024 total average differentials are for the period from October 1 to October 31, 2024.
    (4) Operating netback as presented is defined as oil sales less operating and transportation expenses. See the table titled Financial and Operational Highlights above for the components of consolidated operating netback and corresponding reconciliation.
    (5) Reflects our 1-for-10 reverse stock split that became effective May 5, 2023 and not inclusive of shares of common stock issued in connection with the i3 Energy acquisition on October 31, 2024.


    Conference Call Information:

    Gran Tierra will host its third quarter 2024 results conference call on Monday, November 4, 2024, at 9:00 a.m. Mountain Time, 11:00 a.m. Eastern Time. Interested parties may access the conference call by registering at the following link: https://https://register.vevent.com/register/BIc9cc718f582741cbbf0eb2cfe5a231b1. The call will also be available via webcast at www.grantierra.com.

    Corporate Presentation:

    Gran Tierra’s Corporate Presentation has been updated and is available on the Company website at www.grantierra.com.

    Contact Information

    For investor and media inquiries please contact:

    Gary Guidry
    President & Chief Executive Officer

    Ryan Ellson
    Executive Vice President & Chief Financial Officer

    +1-403-265-3221

    info@grantierra.com

    About Gran Tierra Energy Inc.
    Gran Tierra Energy Inc. together with its subsidiaries is an independent international energy company currently focused on oil and natural gas exploration and production in Canada, Colombia and Ecuador. The Company is currently developing its existing portfolio of assets in Canada, Colombia and Ecuador and will continue to pursue additional new growth opportunities that would further strengthen the Company’s portfolio. The Company’s common stock trades on the NYSE American, the Toronto Stock Exchange and the London Stock Exchange under the ticker symbol GTE. Additional information concerning Gran Tierra is available at www.grantierra.com. Except to the extent expressly stated otherwise, information on the Company’s website or accessible from our website or any other website is not incorporated by reference into and should not be considered part of this press release. Investor inquiries may be directed to info@grantierra.com or (403) 265-3221.

    Gran Tierra’s Securities and Exchange Commission (the “SEC”) filings are available on the SEC website at http://www.sec.gov. The Company’s Canadian securities regulatory filings are available on SEDAR+ at http://www.sedarplus.ca and UK regulatory filings are available on the National Storage Mechanism website at https://data.fca.org.uk/#/nsm/nationalstoragemechanism.

    Forward Looking Statements and Legal Advisories:
    This press release contains opinions, forecasts, projections, and other statements about future events or results that constitute forward-looking statements within the meaning of the United States Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, and financial outlook and forward looking information within the meaning of applicable Canadian securities laws (collectively, “forward-looking statements”). All statements other than statements of historical facts included in this press release regarding our business strategy, plans and objectives of our management for future operations, capital spending plans and benefits of the changes in our capital program or expenditures, our liquidity and financial condition, and those statements preceded by, followed by or that otherwise include the words “expect,” “plan,” “can,” “will,” “should,” “guidance,” “forecast,” “budget,” “estimate,” “signal,” “progress” and “believes,” derivations thereof and similar terms identify forward-looking statements. In particular, but without limiting the foregoing, this press release contains forward-looking statements regarding: the Company’s leverage ratio target, the Company’s plans regarding strategic investments, acquisitions, including the anticipated benefits and operating synergies expected from the acquisition of i3 Energy, and growth, the Company’s drilling program and capital expenditures and the Company’s expectations of commodity prices, including future gas pricing in Canada, exploration and production trends and its positioning for 2024. The forward-looking statements contained in this press release reflect several material factors and expectations and assumptions of Gran Tierra including, without limitation, that Gran Tierra will continue to conduct its operations in a manner consistent with its current expectations, pricing and cost estimates (including with respect to commodity pricing and exchange rates), the ability of Gran Tierra to successfully integrate the assets and operations of i3 Energy or realize the anticipated benefits and operating synergies expected from the acquisition of i3 Energy, the general continuance of assumed operational, regulatory and industry conditions in Canada, Colombia and Ecuador, and the ability of Gran Tierra to execute its business and operational plans in the manner currently planned.

    Among the important factors that could cause our actual results to differ materially from the forward-looking statements in this press release include, but are not limited to: certain of our operations are located in South America and unexpected problems can arise due to guerilla activity, strikes, local blockades or protests; technical difficulties and operational difficulties may arise which impact the production, transport or sale of our products; other disruptions to local operations; global health events; global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil and gas, including inflation and changes resulting from a global health crisis, geopolitical events, including the conflicts in Ukraine and the Gaza region, or from the imposition or lifting of crude oil production quotas or other actions that might be imposed by OPEC and other producing countries and the resulting company or third-party actions in response to such changes; changes in commodity prices, including volatility or a prolonged decline in these prices relative to historical or future expected levels; the risk that current global economic and credit conditions may impact oil prices and oil consumption more than we currently predict. which could cause further modification of our strategy and capital spending program; prices and markets for oil and natural gas are unpredictable and volatile; the effect of hedges; the accuracy of productive capacity of any particular field; geographic, political and weather conditions can impact the production, transport or sale of our products; our ability to execute our business plan, which may include acquisitions, and realize expected benefits from current or future initiatives; the risk that unexpected delays and difficulties in developing currently owned properties may occur; the ability to replace reserves and production and develop and manage reserves on an economically viable basis; the accuracy of testing and production results and seismic data, pricing and cost estimates (including with respect to commodity pricing and exchange rates); the risk profile of planned exploration activities; the effects of drilling down-dip; the effects of waterflood and multi-stage fracture stimulation operations; the extent and effect of delivery disruptions, equipment performance and costs; actions by third parties; the timely receipt of regulatory or other required approvals for our operating activities; the failure of exploratory drilling to result in commercial wells; unexpected delays due to the limited availability of drilling equipment and personnel; volatility or declines in the trading price of our common stock or bonds; the risk that we do not receive the anticipated benefits of government programs, including government tax refunds; our ability to access debt or equity capital markets from time to time to raise additional capital, increase liquidity, fund acquisitions or refinance debt; our ability to comply with financial covenants in our indentures and make borrowings under any future credit agreement; and the risk factors detailed from time to time in Gran Tierra’s periodic reports filed with the Securities and Exchange Commission, including, without limitation, under the caption “Risk Factors” in Gran Tierra’s Annual Report on Form 10-K for the year ended December 31, 2023 filed February 20, 2024 and its other filings with the SEC. These filings are available on the SEC website at http://www.sec.gov and on SEDAR+ at www.sedarplus.ca.

    The forward-looking statements contained in this press release are based on certain assumptions made by Gran Tierra based on management’s experience and other factors believed to be appropriate. Gran Tierra believes these assumptions to be reasonable at this time, but the forward-looking statements are subject to risk and uncertainties, many of which are beyond Gran Tierra’s control, which may cause actual results to differ materially from those implied or expressed by the forward looking statements. The risk that the assumptions on which the 2024 outlook are based prove incorrect may increase the later the period to which the outlook relates. All forward-looking statements are made as of the date of this press release and the fact that this press release remains available does not constitute a representation by Gran Tierra that Gran Tierra believes these forward-looking statements continue to be true as of any subsequent date. Actual results may vary materially from the expected results expressed in forward-looking statements. Gran Tierra disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by applicable law. In addition, historical, current and forward-looking sustainability-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve, and assumptions that are subject to change in the future.

    Following Gran Tierra’s acquisition of i3 Energy, investors should not rely on Gran Tierra’s previously issued financial and production guidance for 2024, which is no longer applicable on a combined company basis.

    Non-GAAP Measures

    This press release includes non-GAAP financial measures as further described herein. These non-GAAP measures do not have a standardized meaning under GAAP. Investors are cautioned that these measures should not be construed as alternatives to net income or loss, cash flow from operating activities or other measures of financial performance as determined in accordance with GAAP. Gran Tierra’s method of calculating these measures may differ from other companies and, accordingly, they may not be comparable to similar measures used by other companies. Each non-GAAP financial measure is presented along with the corresponding GAAP measure so as to not imply that more emphasis should be placed on the non-GAAP measure.

    Operating netback, as presented, is defined as oil sales less operating and transportation expenses. See the table entitled Financial and Operational Highlights above for the components of consolidated operating netback and corresponding reconciliation.

    Return on average capital employed as presented is defined as earnings before interest and taxes (“EBIT”; annualized, if the period is other than one year) divided by average capital employed (total assets minus cash and current liabilities; average of the opening and closing balances for the period).

        Three Months Ended
    September 30,
      Twelve Month Trailing
    September 30,
      As at September 30,
    Return on Average Capital Employed – (Non-GAAP) Measure ($000s)     2024       2024       2024  
    Net Income   $ 1,133     $ 45,137      
    Adjustments to reconcile net income to EBIT:            
    Interest Expense     19,892       74,503      
    Income Tax Expense     20,767       34,589      
    EBIT   $ 41,792     $ 154,229      
                 
    Total Assets           $ 1,533,378  
    Less Current Liabilities             263,492  
    Less Cash and Cash Equivalents             277,645  
    Capital Employed           $ 992,241  
                 
    Annualized EBIT*   $ 167,168          
    Divided by Average Capital Employed     992,241       992,241      
    Return on Average Capital Employed     17 %     16 %    

    *Annualized EBIT was calculated for the three months ended September 30, 2024, by multiplying the quarter-to-date EBIT by 4.

    Cash netback as presented is defined as net income or loss adjusted for DD&A expenses, deferred tax expense or recovery, stock-based compensation expense or recovery, amortization of debt issuance costs, non-cash lease expense, lease payments, unrealized foreign exchange gain or loss and other gain or loss. Management believes that operating netback and cash netback are useful supplemental measures for investors to analyze financial performance and provide an indication of the results generated by Gran Tierra’s principal business activities prior to the consideration of other income and expenses. A reconciliation from net income or loss to cash netback is as follows:

      Three Months Ended
    September 30,
      Three
    Months
    Ended
    June 30,
      Nine Months Ended
    September 30,
    Cash Netback – (Non-GAAP) Measure ($000s)   2024     2023       2024       2024     2023  
    Net Income (Loss) $ 1,133   $ 6,527     $ 36,371     $ 37,426   $ (13,998 )
    Adjustments to reconcile net income (loss) to cash netback              
    DD&A expenses   55,573     55,019       55,490       167,213     163,424  
    Deferred tax expense (recovery)   5,550     13,990       (51,361 )     (32,332 )   43,242  
    Stock-based compensation (recovery) expense   (3,145 )   1,931       6,160       6,376     3,748  
    Amortization of debt issuance costs   3,109     1,594       2,760       9,175     3,394  
    Non-cash lease expense   1,370     1,235       1,381       4,164     3,488  
    Lease payments   (1,171 )   (676 )     (1,311 )     (3,540 )   (1,918 )
    Unrealized foreign exchange gain   (2,081 )   (266 )     (3,323 )     (7,670 )   (7,814 )
    Other gain       (354 )               (1,444 )
    Cash netback $ 60,338   $ 79,000     $ 46,167     $ 180,812   $ 192,122  

    EBITDA, as presented, is defined as net income or loss adjusted for DD&A expenses, interest expense and income tax expense or recovery. Adjusted EBITDA, as presented, is defined as EBITDA adjusted for non-cash lease expense, lease payments, foreign exchange gain or loss, stock-based compensation expense, transaction costs and other gain or loss. Management uses this supplemental measure to analyze performance and income generated by our principal business activities prior to the consideration of how non-cash items affect that income, and believes that this financial measure is useful supplemental information for investors to analyze our performance and our financial results. A reconciliation from net income or loss to EBITDA and adjusted EBITDA is as follows:

      Three Months Ended
    September 30,
      Three
    Months
    Ended
    June 30,
      Nine Months Ended
    September 30,
    EBITDA – (Non-GAAP) Measure ($000s)   2024     2023       2024       2024     2023  
    Net Income (Loss) $ 1,133   $ 6,527     $ 36,371     $ 37,426   $ (13,998 )
    Adjustments to reconcile net income (loss) to EBITDA and Adjusted EBITDA              
    DD&A expenses   55,573     55,019       55,490       167,213     163,424  
    Interest expense   19,892     13,503       18,398       56,714     38,017  
    Income tax expense (recovery)   20,767     40,333       (9,072 )     29,090     106,948  
    EBITDA $ 97,365   $ 115,382     $ 101,187     $ 290,443   $ 294,391  
    Non-cash lease expense   1,370     1,235       1,381       4,164     3,488  
    Lease payments   (1,171 )   (676 )     (1,311 )     (3,540 )   (1,918 )
    Foreign exchange (gain) loss   (3,084 )   1,717       (4,413 )     (8,312 )   8,126  
    Stock-based compensation expense   (3,145 )   1,931       6,160       6,376     3,748  
    Transaction costs   1,459                 1,459      
    Other loss (gain)       (354 )               (1,444 )
    Adjusted EBITDA $ 92,794   $ 119,235     $ 103,004     $ 290,590   $ 306,391  

    Funds flow from operations, as presented, is defined as net income or loss adjusted for DD&A expenses, deferred tax expense or recovery, stock-based compensation expense, amortization of debt issuance costs, non-cash lease expense, lease payments, unrealized foreign exchange gain, and other gain or loss. Management uses this financial measure to analyze performance and income or loss generated by our principal business activities prior to the consideration of how non-cash items affect that income or loss, and believes that this financial measure is also useful supplemental information for investors to analyze performance and our financial results. Free cash flow, as presented, is defined as funds flow from operations adjusted for capital expenditures. Management uses this financial measure to analyze cash flow generated by our principal business activities after capital requirements and believes that this financial measure is also useful supplemental information for investors to analyze performance and our financial results. A reconciliation from net income or loss to both funds flow from operations and free cash flow is as follows:

      Three Months Ended
    September 30,
      Three
    Months
    Ended
    June 30,
      Nine Months Ended
    September 30,
    Funds Flow From Operations –
    (Non-GAAP) Measure ($000s)
      2024     2023       2024       2024     2023  
    Net Income (Loss) $ 1,133   $ 6,527     $ 36,371     $ 37,426   $ (13,998 )
    Adjustments to reconcile net income (loss) to funds flow from operations              
    DD&A expenses   55,573     55,019       55,490       167,213     163,424  
    Deferred tax expense (recovery)   5,550     13,990       (51,361 )     (32,332 )   43,242  
    Stock-based compensation (recovery) expense   (3,145 )   1,931       6,160       6,376     3,748  
    Amortization of debt issuance costs   3,109     1,594       2,760       9,175     3,394  
    Non-cash lease expense   1,370     1,235       1,381       4,164     3,488  
    Lease payments   (1,171 )   (676 )     (1,311 )     (3,540 )   (1,918 )
    Unrealized foreign exchange gain   (2,081 )   (266 )     (3,323 )     (7,670 )   (7,814 )
    Other loss (gain)       (354 )               (1,444 )
    Funds flow from operations $ 60,338   $ 79,000     $ 46,167     $ 180,812   $ 192,122  
    Capital expenditures $ 52,921   $ 43,080     $ 61,273     $ 169,525   $ 179,707  
    Free cash flow $ 7,417   $ 35,920     $ (15,106 )   $ 11,287   $ 12,415  

    Net debt as of September 30, 2024, was $509 million, calculated using the sum of the aggregate principal amount of 6.25% Senior Notes, 7.75% Senior Notes, and 9.50% Senior Notes outstanding, excluding deferred financing fees, totaling $787 million, less cash and cash equivalents of $278 million.

    Presentation of Oil and Gas Information

    All reserves value and ancillary information contained in this press release regarding Gran Tierra (not including reserves value and ancillary information regarding i3 Energy) have been prepared by the Company’s independent qualified reserves evaluator McDaniel & Associates Consultants Ltd. (“McDaniel”) in a report with an effective date of December 31, 2023 (the “Gran Tierra McDaniel Reserves Report”) and calculated in compliance with Canadian National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”) and the Canadian Oil and Gas Evaluation Handbook (“COGEH”), unless otherwise expressly stated. All reserves value and ancillary information contained in this press release regarding i3 Energy have been prepared by i3 Energy’s independent qualified reserves evaluator GLJ Ltd. (“GLJ”) in a fair market value report with an effective date of July 31, 2024 (the “i3 Energy GLJ Report”) and calculated in compliance with NI 51-101 and COGEH, unless otherwise expressly stated.

    Barrel of oil equivalents (“boe”) have been converted on the basis of six thousand cubic feet (“Mcf”) natural gas to 1 bbl of oil. Boe’s may be misleading, particularly if used in isolation. A boe conversion ratio of 6 Mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. In addition, given that the value ratio based on the current price of oil as compared with natural gas is significantly different from the energy equivalent of six to one, utilizing a boe conversion ratio of 6 Mcf: 1 bbl would be misleading as an indication of value.

    The following reserves categories are discussed in this press release: Proved (“1P”), 1P plus Probable (“2P”) and 2P plus Possible (“3P”) and Proved Developed Producing (“PDP”). Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves. Probable reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves. Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of proved plus probable plus possible reserves. Proved developed producing reserves are those proved reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty. Certain terms used in this press release but not defined are defined in NI 51-101, CSA Staff Notice 51-324 – Revised Glossary to NI 51-101 Standards of Disclosure for Oil and Gas Activities (“CSA Staff Notice 51-324”) and/or the COGEH and, unless the context otherwise requires, shall have the same meanings herein as in NI 51-101, CSA Staff Notice 51-324 and the COGEH, as the case may be.

    Estimates of reserves for individual properties may not reflect the same level of confidence as estimates of reserves for all properties, due to the effect of aggregation. There is no assurance that the forecast price and cost assumptions applied by McDaniel or GLJ in evaluating Gran Tierra’s or i3 Energy’s reserves, respectively, will be attained and variances could be material. There are numerous uncertainties inherent in estimating quantities of crude oil and natural gas reserves. The reserves information set forth in the Gran Tierra McDaniel Reserves Report and the i3 Energy GLJ Report are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided therein. All reserves assigned in the Gran Tierra McDaniel Reserves Report are located in Colombia and Ecuador and presented on a consolidated basis by foreign geographic area.

    Booked drilling locations of i3 Energy disclosed herein are derived from the i3 Energy GLJ Report and account for drilling locations that have associated 2P reserves.

    References to a formation where evidence of hydrocarbons has been encountered is not necessarily an indicator that hydrocarbons will be recoverable in commercial quantities or in any estimated volume. Gran Tierra’s reported production is a mix of light crude oil and medium and heavy crude oil for which there is not a precise breakdown since the Company’s oil sales volumes typically represent blends of more than one type of crude oil. Well test results should be considered as preliminary and not necessarily indicative of long-term performance or of ultimate recovery. Well log interpretations indicating oil and gas accumulations are not necessarily indicative of future production or ultimate recovery. If it is indicated that a pressure transient analysis or well-test interpretation has not been carried out, any data disclosed in that respect should be considered preliminary until such analysis has been completed. References to thickness of “oil pay” or of a formation where evidence of hydrocarbons has been encountered is not necessarily an indicator that hydrocarbons will be recoverable in commercial quantities or in any estimated volume.

    This press release contains certain oil and gas metrics, including operating netback and cash netback, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. These metrics are calculated as described in this press release and management believes that they are useful supplemental measures for the reasons described in this press release.

    Such metrics have been included herein to provide readers with additional measures to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods.

    References in this press release to IP30, IP90 and other short-term production rates of Gran Tierra are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long-term performance or of ultimate recovery. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Gran Tierra. Gran Tierra cautions that such results should be considered to be preliminary.

    Disclosure of Reserve Information and Cautionary Note to U.S. Investors

    Unless expressly stated otherwise, all estimates of proved, probable and possible reserves and related future net revenue disclosed in this press release have been prepared in accordance with NI 51-101. Estimates of reserves and future net revenue made in accordance with NI 51-101 will differ from corresponding estimates prepared in accordance with applicable SEC rules and disclosure requirements of the U.S. Financial Accounting Standards Board (“FASB”), and those differences may be material. NI 51-101, for example, requires disclosure of reserves and related future net revenue estimates based on forecast prices and costs, whereas SEC and FASB standards require that reserves and related future net revenue be estimated using average prices for the previous 12 months. In addition, NI 51-101 permits the presentation of reserves estimates on a “company gross” basis, representing Gran Tierra’s working interest share before deduction of royalties, whereas SEC and FASB standards require the presentation of net reserve estimates after the deduction of royalties and similar payments. There are also differences in the technical reserves estimation standards applicable under NI 51-101 and, pursuant thereto, the COGEH, and those applicable under SEC and FASB requirements.

    In addition to being a reporting issuer in certain Canadian jurisdictions, Gran Tierra is a registrant with the SEC and subject to domestic issuer reporting requirements under U.S. federal securities law, including with respect to the disclosure of reserves and other oil and gas information in accordance with U.S. federal securities law and applicable SEC rules and regulations (collectively, “SEC requirements”). Disclosure of such information in accordance with SEC requirements is included in the Company’s Annual Report on Form 10-K and in other reports and materials filed with or furnished to the SEC and, as applicable, Canadian securities regulatory authorities. The SEC permits oil and gas companies that are subject to domestic issuer reporting requirements under U.S. federal securities law, in their filings with the SEC, to disclose only estimated proved, probable and possible reserves that meet the SEC’s definitions of such terms. Gran Tierra has disclosed estimated proved, probable and possible reserves in its filings with the SEC. In addition, Gran Tierra prepares its financial statements in accordance with United States generally accepted accounting principles, which require that the notes to its annual financial statements include supplementary disclosure in respect of the Company’s oil and gas activities, including estimates of its proved oil and gas reserves and a standardized measure of discounted future net cash flows relating to proved oil and gas reserve quantities. This supplementary financial statement disclosure is presented in accordance with FASB requirements, which align with corresponding SEC requirements concerning reserves estimation and reporting.

    The MIL Network

  • MIL-OSI Global: Maia Sandu’s victory in second round of Moldovan election show’s limits to Moscow’s meddling

    Source: The Conversation – UK – By Stefan Wolff, Professor of International Security, University of Birmingham

    Following a campaign marred by widespread and credible allegations of massive interference by Russia and pro-Russian proxies, Moldova’s incumbent president, Maia Sandu, has won another term in the second round of presidential elections.

    According to preliminary results published by the country’s central electoral commission on November 3, Sandu beat her second-round challenger, Alexandr Stoianoglo, with 55% of the vote and on a higher turnout than in the first round of elections on October 20.

    There were more than 180,000 votes between the incumbent and her challenger. In a country with an electorate of just over three million people, this is a significant margin, especially when compared with the razor-thin yes vote in the EU referendum that was on the same day as the first round of the presidential election two weeks ago. In that election, Sandu came first with 42%, compared to Staionoglo’s 26%, but in the EU poll, just 10,000 votes separated the yes and the no votes.

    Sandu, who campaigned on a strongly pro-European platform, prevailed despite pro-Russian interference and fearmongering and a campaign by Stoianoglo that emphasised the importance of good relations with both Moscow and Brussels.

    Moldova’s election result will certainly have come as a relief not only to Sandu and her supporters but also to Moldova’s western partners. It is the first time that a popularly elected president has won a second term in the tiny landlocked former Soviet satellite. The country borders Romania and Ukraine and has a small but significant Russian breakaway region, Transnistria, as a constant reminder of Moscow’s influence in the region.

    Moldova’s election presents a clear difference to the Georgian parliamentary election results on October 26, which saw an openly pro-Russian Georgian Dream party win an election considered as neither particularly free nor fair, in results that the Georgia’s opposition-aligned president and western pollsters allege have been rigged.

    Sandu’s win, by contrast, demonstrates both the appeal of the idea of a European future and the limits of Russian interference. Yet the understandable enthusiasm about the result in Moldova also needs to be tempered by a more careful analysis of some of the deeply entrenched societal cleavages that the elections have all but confirmed and the difficulties that lie ahead.

    Deep divisions

    Sandu’s win overall looks impressive. But she did not win the vote in Moldova itself, where Stoianoglo beat her by some 30,000 votes. What saved Sandu, like the EU referendum, was the strong support for her among voters in the diaspora, where she captured almost five times as many votes as Stoianoglo.

    Just over 270,000 votes (83%) of the votes cast by Moldovans living abroad, predominantly in western Europe and north America, saw her comfortably across the finishing line. There may be good reasons not to distinguish between votes from inside and outside Moldova – but the optics are not good.

    Nor can the overall margin of Sandu’s victory gloss over the fact that her supporters inside the country are predominantly concentrated in the capital and the centre of the country. In the capital Chisinau, in the centre of Moldova, Sandu won with 57%, representing almost one-third of her total vote inside the country. In the north and south of the country, Stoianoglo generally took the largest vote share.

    In the country’s second-largest city, Balti in the north, he won 70% of the vote, compared to Sandu’s 30%. In the southern autonomous region of Gagauzia, a hotbed of pro-Russian, anti-European activism, Sandu obtained less than 3%. In Transnistria, Sandu came away with just 20% of the vote.

    Map of Moldova showing the breakaway regions of Transnistria and Gaugazia.
    Institute for the Study of War

    These results are not surprising, given the outcome of the first round of the elections. But they represent fall in support for Sandu compared to in 2020, when she beat the then incumbent, socialist party leader Igor Dodon. Four years ago, Sandu obtained over 250,000 votes more than Dodon, winning almost 58% of the total vote. While she took the overwhelming share of the diaspora vote then as well, she also bested Dodon in most constituencies in the south.

    Dodon campaigned for Stoianoglo in this election, but much of the challenger’s support was very probably due to a massive pro-Russian interference campaign that capitalised on many Moldovans’ fears and frustrations. Pro-Moscow messages aimed to capitalise on fears about being dragged into Russia’s war against Ukraine.

    But there was also frustration with a government that has made little progress on much needed anti-corruption reforms and presided over a serious cost-of-living crisis in the aftermath of the Covid-19 pandemic and made worse by the war on Moldova’s eastern neighbour. Sandu’s party, the Party of Action and Solidarity (PAS) won a commanding majority in the 2021 elections – so failures of the government are seen as failures of Sandu and her agenda.

    Challenges ahead

    That Sandu won the presidency again, and against these odds, demonstrates her resilience. But it can’t be taken for granted that her party will similarly prevail in parliamentary elections due by the autumn of 2025. She may well be forced into a difficult cohabitation with a potentially socialist-led government next year. In a parliamentary democracy, in which the powers of the government by far exceed those of the president, this could significantly slow down Moldova’s EU accession negotiations.

    But there are also some silver linings on the horizon. That Sandu won clearly demonstrates the limits of Russian interference. There is a core part of the Moldovan electorate that cannot be swayed by Russian misinformation or vote buying. This is a basis on which Sandu and PAS can build.

    Perhaps more importantly, Sandu and Stoianoglo both sent conciliatory signals on election eve. Stoianoglo emphasised the importance of respecting the outcome of the democratic process and expressed the hope that Moldovans would now move beyond hatred and division. Sandu acknowledged the concerns of those who had not voted for her and promised to serve as the president of all Moldovans and to work for the country’s further development.

    If they both stay true to their word, Moldova may finally break with a past of repeated political crises and economic stagnation.

    Stefan Wolff is a past recipient of grant funding from the Natural Environment Research Council of the UK, the United States Institute of Peace, the Economic and Social Research Council of the UK, the British Academy, the NATO Science for Peace Programme, the EU Framework Programmes 6 and 7 and Horizon 2020, as well as the EU’s Jean Monnet Programme. He is a Trustee and Honorary Treasurer of the Political Studies Association of the UK and a Senior Research Fellow at the Foreign Policy Centre in London.

    ref. Maia Sandu’s victory in second round of Moldovan election show’s limits to Moscow’s meddling – https://theconversation.com/maia-sandus-victory-in-second-round-of-moldovan-election-shows-limits-to-moscows-meddling-242796

    MIL OSI – Global Reports

  • MIL-OSI Europe: VATICAN/ANGELUS – All Saints Day: “How much hidden saintliness there is in the Church!”

    Source: Agenzia Fides – MIL OSI

    VATICAN/ANGELUS – All Saints Day: “How much hidden saintliness there is in the Church!”Vatican City (Agenzia Fides) – The Beatitudes are “the Christian’s identity card” and “the way to holiness”. This was stated by Pope Francis during the Angelus prayer on the Solemnity of All Saints Day.Referring to the Gospel of the day, the Pope recalled that holiness is both “a gift from God” and “our response to God”.“It is a gift from God because, as Saint Paul says, it is He who sanctifies. With His grace, He heals us and frees us from all that prevents us from loving as He loves us, as Blessed Carlo Acutis used to say, there may always be ‘less of me to make room for God’”, stressed the Bishop of Rome, adding that God “offers us His holiness, but He does not impose it. He leaves us the freedom to engage in his plans”.All this, Pope Francis continued, “we see all of this in the life of the saints, even in our time”. In this context, the Pope recalled Saint Maximilian Kolbe, Saint Teresa of Calcutta and Saint Oscar Romero: “We we can make a list of many saints, many of them: those we venerate on the altars and others, that I like to call the saints “next door”, the everyday ones, hidden, who go forward in their daily Christian life”.“How much hidden saintliness there is in the Church!” said the Pope. “We recognize so many brothers and sisters formed by the Beatitudes: poor, meek, merciful, hungry and thirsty for justice, workers for peace. They are people “filled with God”, incapable of remaining indifferent to the needs of their neighbour; they are witnesses of shining paths, possible for us too”.After the Angelus, the Pope’s thoughts turned to the Holy Land and he warned: “War is always a defeat, always! And it is ignoble, because it is the triumph of the lie, of falsehood.” He recalled the suffering of the innocent: “I think of the 153 women and children massacred in Gaza in recent days,” said the Pope, who described the war not only as a triumph of lies, but also of falsehood, because “they seek the greatest self-interest and the greatest damage to the enemy, trampling on human lives, the environment, the infrastructure, everything; and all of this is disguised with lies,” said the Pope. He again called for prayer: “Let us pray for tormented Ukraine, let us pray for Palestine, Israel, Lebanon, Myanmar, Sudan, and for all the peoples who are suffering because of war.” Pope Francis also expressed his “closeness to the people of Chad, in particular the families of the victims of the grave terrorist attack a few days ago, as well as those who have been affected by floods. And in the face of these environmental disasters, let us pray for the populations of the Iberian Peninsula, especially the Valencian community: for the deceased and their loved ones, and for all the damaged families. May the Lord sustain those who are suffering, and those who are bringing relief”.Finally, thinking of tomorrow, Saturday 2 November, the day on which the deceased are commemorated, Pope Francis recalled: “Those who can, go in these days to pray at the tomb of your own loved ones. Let us not forget: the Eucharist is the greatest and most effective prayer for the soul of the departed”. (FB) (Agenzia Fides, 1/11/2024)
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    MIL OSI Europe News

  • MIL-OSI: authID Signs $10 Million Agreement to Deliver Next Generation Authentication Security in India

    Source: GlobeNewswire (MIL-OSI)

    DENVER, Nov. 04, 2024 (GLOBE NEWSWIRE) — authID Inc. (Nasdaq: AUID), a leading provider of biometric identity verification and authentication solutions, today announced a $10 million, multi-year agreement with a next-generation AI company specializing in custom solutions for global multi-national companies to enable authentication for a range of industries in India.

    The agreement represents a $10 million commitment over a three-year period, with a minimum of $3.33 million each year for licensing authID’s identity platform services.

    authID will deliver unprecedented biometric authentication accuracy and a frictionless user experience to a variety of the partner’s customers across the banking, financial services, emergency services, and transportation industries among others, powering use cases for onboarding, daily login, account recovery, and high-value transactions.

    authID will augment the partner’s existing solutions with their privacy-preserving next generation biometric identity verification and authentication, while complying with Indian privacy laws safeguarding user identities and other data. The Indian market’s sizable institutional and end-user base will highlight authID’s ability to not only deliver a best-in-class user experience but also demonstrate its 1:1B biometric identity verification accuracy.  With over 1.4B citizens to authenticate in the Indian market, only authID’s accuracy can deliver the level of assurance and scale needed by every institution to always “know who’s behind the device” for each transaction.

    “This partnership further demonstrates authID’s thought leadership and technical standing in the global markets, and we are incredibly excited to enter the Indian market where, over the next 10 years, the biometric authentication industry could see exponential growth in transaction volumes as the demand for secure, efficient digital identification continues to rise,” said Rhon Daguro, CEO of authID. “authID’s biometric identity platform delivers speed and accuracy while processing captured biometrics, and identifying users as legitimate or fraudulent, all within a market-leading 700 milliseconds. We look forward to working closely with our new partner to deliver the confidence that user onboarding and authentication are accurate and completed in record time.”

    About authID

    authID (Nasdaq: AUID) ensures enterprises “Know Who’s Behind the DeviceTM” for every customer or employee login and transaction through its easy-to-integrate, patented, biometric identity platform. authID quickly and accurately verifies a user’s identity and eliminates any assumption of ‘who’ is behind a device to prevent cybercriminals from compromising account openings or taking over accounts. Combining secure digital onboarding, and biometric authentication and account recovery, with a fast, accurate, user-friendly experience, authID delivers biometric identity processing in 700ms. Binding a biometric root of trust for each user to their account, authID stops fraud at onboarding, detects and stops deepfakes, eliminates password risks and costs, and provides the fastest, frictionless, and the more accurate user identity experience while preserving privacy demanded by today’s digital ecosystem. Contact us to discover how authID can help your organization secure your workforce or consumer applications against identity fraud, cyberattacks and account takeover.

    Investor Relations Contacts

    Gateway Group, Inc. 
    Cody Slach and Alex Thompson
    1-949-574-3860
    AUID@gateway-grp.com
    Investor-Relations@authid.ai  

    Media Contacts

    Walter Fowler
    1-631-334-3864
    wfowler@nexttechcomms.com

    Forward-Looking Statements

    This Press Release includes “forward-looking statements.” All statements other than statements of historical facts included herein, including, without limitation, those regarding the future business strategy, plans and objectives of management for future operations of both authID Inc. and its customers and business partners, are forward-looking statements. Such forward-looking statements are based on a number of assumptions regarding authID’s present and future business strategies, and the environment in which authID expects to operate in the future, which assumptions may or may not be fulfilled in practice. Actual results may vary materially from the results anticipated by these forward-looking statements as a result of a variety of risk factors, including the successful implementation and ramp of the services to be provided under the new technology partner agreement and their adoption by the partner’s customers and their respective users; changes in laws, regulations and practices; changes in domestic and international economic and political conditions, the as yet uncertain impact of the wars in Ukraine and the Middle East, inflationary pressures, changes in interest rates, and others. See the Company’s Annual Report on Form 10-K for the Fiscal Year ended December 31, 2023 filed at www.sec.gov and other documents filed with the SEC for other risk factors which investors should consider. These forward-looking statements speak only as to the date of this release and cannot be relied upon as a guide to future performance. authID expressly disclaims any obligation or undertaking to disseminate any updates or revisions to any forward-looking statements contained in this release to reflect any changes in its expectations with regard thereto or any change in events, conditions, or circumstances on which any statement is based.

    The MIL Network

  • MIL-OSI Europe: Frank Elderson: The first decade of European supervision: taking stock and looking ahead

    Source: European Central Bank

    Keynote speech by Frank Elderson, Member of the Executive Board of the ECB and Vice-Chair of the Supervisory Board of the ECB at the “10 Years of SSM – Looking back and looking forward” conference organised by the European Banking Institute and the Hessisches Ministerium für Wissenschaft und Kunst

    Frankfurt am Main, 4 November 2024

    Introduction

    Thank you for your kind invitation. It’s a pleasure to be with you this afternoon to reflect on the first decade of European banking supervision and, most importantly, to take a look at the path ahead of us.

    On this day ten years ago, the morning might have seemed just like a typical November morning in Frankfurt’s Bankenviertel: a rainy autumn day, with people heading to their offices armed with umbrellas, wearing heavy coats.

    But that day ten years ago was anything but typical.

    Because it was the first time European supervisory teams got together and started work on an important task: making sure the banking system is safe and sound on behalf of European citizens.

    At the time, some argued that integrating a fragmented system of supervision was either impossible or would take forever. Well, those pioneer European supervisors who came together on 4 November 2014 have certainly proven the sceptics wrong.

    We have come a long way since that day. The last ten years have been transformative both for the Single Supervisory Mechanism (SSM) and the banks we supervise. We have evolved from a start-up to a mature, risk-based and effective supervisor. Banks under our supervision have also evolved significantly, building up remarkable resilience. Unlike in the crises that predated the banking union, banks have now become part of the solution to economic shocks rather than the source. That’s good news.

    There is, however, no room for complacency.

    While past achievements provide a solid foundation, they are by no means a guarantee of future success. The macro-financial environment is changing profoundly. Unlike ten years ago, when the main risks emanated from banks themselves, today prudential risks are largely driven by an increasingly volatile and uncertain external environment.

    In my remarks, I will therefore focus on how supervisors and banks must adapt to this challenging environment. I will also address suggestions being put forward by some to relax banking regulation and supervision – suggestions which in my view are misguided. Compromising the resilience that has been carefully built up over the past ten years would undermine the objective of having a financial system that can support a competitive and sustainable economy.

    The first decade of European supervision: from start-up to maturity

    But before focusing on current challenges, I hope you’ll allow me to take a brief walk down memory lane. Where did we start from? What were the expectations a decade ago? And how did we go about meeting them?

    As Europe was looking into the abyss of the euro area sovereign debt crisis in 2012, legislators agreed on nothing less than a paradigm shift – the banking union, which represented the most significant leap forward in European integration since the introduction of the euro.

    The banking union encompasses three pillars, each with a straightforward task: first, European banking supervision to ensure that banks across Europe are subject to the same rules and high-quality supervisory standards. Second, European resolution to make sure that if banks fail, they can get resolved in an orderly manner instead of relying on the public purse. And third, European deposit insurance, to make sure that when push comes to shove, all depositors enjoy the same protection, no matter where in the euro area they are based.

    As far as the supervisory pillar is concerned, the ECB and the national competent authorities that make up the SSM were given a clear mission: ensuring the safety and soundness of banks. This is not just an end in itself – it is necessary so that banks remain at the service of people and businesses by funding innovation, productivity and sustainable growth.

    The destination was clear. But we had no roadmap to show us how to get there. There was no blueprint on how to transform a fragmented system of supervision into an integrated one. So it was by no means a given that the SSM would be a success.

    In the start-up phase of the SSM we were essentially crossing the bridge we were still building: we spent the mornings recruiting the best risk experts from across Europe, the afternoons supervising significant banks, and the evenings setting up our processes.

    When we started, there were plenty of ways in which supervisors across Europe looked at risks and how best to mitigate them. They all focused on different things: while some put the emphasis on credit file reviews, others focused on scrutinising banks’ internal risk management through the lens of the internal capital adequacy assessment process. Some supervisors chose to shine the spotlight more closely on governance or on-site culture.

    Thanks to the unwavering commitment and tireless energy of supervisors from the national competent authorities and the ECB, we consolidated the best practices from this wealth of supervisory experience into a common supervisory approach. What followed was a race to the top rather than to the bottom, resulting in high-quality supervision and a level playing field.

    On our path to becoming a mature organisation, we have adapted our processes along the way. Our supervision has evolved from being predominantly rule-based and heavily codified, to having a more flexible, agile and risk-focused approach.

    And banks under our supervision have also evolved significantly over the past ten years. Today, European banks are in much better shape than a decade ago.

    For instance, the financial resilience of SSM banks has notably improved. The aggregate Common Equity Tier 1 (CET1) ratio has increased from 12.7% in 2015 to 15.8% today, the liquidity coverage ratio has increased from 138% in 2016 to 159% today and the non-performing loan ratio of significant banks has declined from 7.5% in 2015 to 1.9% today.[1]

    Moreover, risk management, the effectiveness of internal control functions and governance arrangements in SSM banks have all improved.

    Over the past ten years, banks under European supervision have shown remarkable resilience even under the most challenging circumstances. They have evolved from shock propagators to shock absorbers, stabilising rather than de-stabilising the economy as it experienced significant shocks such as the pandemic, Russia’s unjustified war against Ukraine and the rapid changes to the interest rate environment. This resilience is also a testament to the crucial role played by European supervision, confirming that the SSM has lived up to the expectations that were placed on it a decade ago.[2]

    Highly complex, volatile and challenging risk landscape

    But there is no room for complacency. We can’t assume that the achievements of the past ten years will automatically pave the way for another successful decade of resilient banks under European supervision.

    We can’t ignore the fact that the world around us is changing. The macro-financial environment is characterised by unprecedented shocks, giving rise to new risk drivers. In the words of President Lagarde, in the last three years alone we have “faced the worst pandemic since the 1920s, the worst conflict in Europe since the 1940s and the worst energy shock since the 1970s”.[3]

    And as former US Treasury secretary Larry Summers put it, “this is the most complex, disparate and cross-cutting set of challenges that I can remember in the 40 years that I have been paying attention to such things’’.[4]

    In fact, the current combination of risks, challenges and uncertainties is staggering.

    A widening geopolitical divide and a global economy that is fragmenting into competing, increasingly protectionist blocs, give rise to new geopolitical risks.

    Heightened operational headwinds such as ever-more sophisticated cyberattacks and technology disruptions are challenging banks’ operational resilience.

    And last, but, alas, not least, we see the climate and nature crises unfolding, as evidenced by the horrific events last week in Paiporta and other villages and towns in the Spanish region of Valencia. On top of the human tragedy and physical destruction, the climate and nature crises are increasingly leading to material risks for banks.

    What makes this period so unprecedented is that these challenges are not happening one after the other – they are all happening at the same time. And there is no clear sign of them going away any time soon, rather the contrary.

    So how can supervisors and banks adjust to this era of polycrises?

    Ensuring bank resilience in the era of polycrises

    First and foremost, banks’ management bodies are the ones holding the steering wheel and must ensure that banks remain resilient and prepared for this new risk landscape. This involves making sure that banks have sound risk management that is commensurate to new risk drivers, that they maintain sufficient capital headroom to cushion against credible adverse scenarios, and that banks’ management bodies are effective in their steering and oversight function.

    While acknowledging that banks’ management bodies are in the driving seat, as supervisors we keep a close eye to ensure that no material risks are left unaddressed.[5] This means that we must be able to identify the risks and then ensure that banks are resilient to these risks.

    To ensure that our risk identification can keep up with the changing risk landscape, we have made our supervisory processes more agile. We simply cannot look at every risk with the same intensity, every year, in every bank we supervise. We have therefore started to implement a supervisory risk tolerance framework aiming at freeing up the desks and minds of supervisors. This allows our supervisors to focus on those risks that are most pertinent and the supervisory actions that are most impactful. In the same vein, we have also reformed our Supervisory Review and Evaluation Process (SREP) to make it more targeted and risk-based. Moreover, we are increasingly using supervisory technology tools – also known as suptech – to detect risks early on and move closer to real-time supervision.[6]

    These improvements to our processes give our supervisory teams more time to focus on the most relevant risks. By detecting vulnerabilities that would otherwise only surface later, we help banks to be better prepared and build up resilience proactively.

    Let me illustrate this with an example. Threats from cyberattacks are on the increase and are challenging banks’ operational resilience. In 2022, 50% of our supervised entities were subject to at least one successful attack – that number rose to 68% in just one year.[7] In order to help banks better identify their vulnerabilities to cyber risks and bolster their operational resilience, earlier this year we conducted a cyber resilience stress test[8] to gauge how well banks would be able to respond to and recover from a successful cyberattack while maintaining their critical functions and services. The cyber resilience stress test was an important learning exercise for banks; it helped them pinpoint areas where they need to build greater operational resilience to cyberattacks, which are unlikely to fade away in the current geopolitical risk environment.

    Let’s shift our focus from risk identification to remediation. As supervisors we must ensure that the risks we identify in our risk assessments are adequately managed. This also means that if we find deficiencies in the way banks are managing their risks, they must be remediated fully and in a timely manner, not at some unspecified point in the distant future. This is why we are putting more emphasis on impact and effectiveness.[9]

    To ensure full and timely remediation of our supervisory findings, we set out a time-bound remediation path. If a bank is not remedying the deficiency at a speed that will ensure full and timely remediation by the pre-established timeline, we will step up our supervisory action by deploying more intrusive measures from our ample supervisory toolkit. This is what we call the “escalation ladder”.

    The use of supervisory powers to compel banks to make concrete improvements is not just something we do within the SSM; it is international best practice.[10] The disorderly events of the March 2023 banking turmoil were a clear reminder of what can happen when banks leave material shortcomings unaddressed for too long.

    Banks and supervisors need to have the capacity to focus on emerging challenges. That’s why it is important to declutter our desks by tackling supervisory findings that have been with us for too long. While this is always an imperative, it is especially pertinent in the current challenging risk landscape.

    Let me illustrate this with the example of risk data aggregation and reporting. It is very hard to imagine any bank being able to appropriately manage its risks without strong risk data reporting. A bank’s ability to manage and aggregate risk-related data effectively is a pre-requisite for sound decision-making and robust risk governance. In fact, the Capital Requirements Directive, as transposed into national law, requires banks to put processes in place to identify all material risks. Worryingly, risk data aggregation and reporting was the lowest-scoring sub-category of internal governance in the 2023 SREP. In other words, despite the work done by supervisors over the years, too many banks still don’t have adequate risk data aggregation and reporting capabilities.

    It should not be a surprise that ECB Banking Supervision is stepping up the escalation ladder, using more intrusive supervisory tools to ensure that banks have adequate risk data aggregation capabilities. It’s not about forcing banks to do something that is merely an added perk; it’s about making sure they are able to manage material risks adequately and in good time. In a rapidly changing risk environment where prompt availability of reliable data has become essential, timely remediation of our supervisory findings on risk data aggregation is more important than ever.

    Deregulation and lenient supervision would compromise resilience

    After a decade of European supervision, it is not only the external risk environment that has changed. The current debate suggests that the perception by some of the role of financial regulation and supervision is also changing.

    Ten years ago, with the gloomy memories of the global financial crisis lingering in people’s minds, there was a strong consensus across society on the need for strong financial regulation and supervision in order to safeguard the public good of financial stability.

    Today, it appears that the pendulum is slowly swinging in the opposite direction. Some have raised the question as to whether regulation and supervision have become too conservative, to the point that they may constrain growth.

    Let me be clear: the argument being put forward in favour of relaxing banking regulation and supervision in order to promote growth is misguided.[11]

    We can’t allow the memory of the global financial crisis to fade. Its lessons are as relevant today as they were back in 2012, when the banking union was created. As deputy governor of the Bank of England, Sam Woods, correctly said, the great financial crisis was “the biggest growth-destroying event in recent economic history”.[12] The crisis was a stark reminder of the economic, social and fiscal hardship that weakly regulated and supervised banks can cause for people. The last thing we should do is ignore the lessons of the financial crisis and allow a regulatory race to the bottom, which would compromise the resilience that has been carefully built up over the last decade.

    It is a fundamental misconception to frame safety and competitiveness as opposing forces.

    It is essential to remember that resilient and well-capitalised banks are a pre-condition for competitiveness and sustainable growth.

    Strong and resilient banks are best equipped to lend to the real economy, funding innovation, investment and growth, even during economic downturns.[13] Banking deregulation or more lenient supervision would weaken the foundations of growth.

    It is true that European growth has been sluggish when compared with other regions, and addressing it is rightly a top priority. That is why we need policies to tackle the root causes of low productivity, promote innovation and bolster the single European market.

    For instance, the EU will need an additional €5.4 trillion between 2025 and 2031 to advance our green transformation, accelerate the digitalisation of our economy and bolster our defence capabilities.[14] Faced with this mammoth task, deepening the capital markets union to help guide the required financing flows should be our highest priority. This will help channel private investments towards supporting innovation and the twin green and digital transition – ultimately fostering EU competitiveness.

    To speed up the integration of a single banking market in Europe, we should now move forward and complete the banking union.

    As a first step, we must enhance the crisis management and deposit insurance framework so that the failures of small and medium-sized banks can be dealt with more effectively.

    Second, we would welcome if Member States were to resume discussions on setting-up a European-level public backstop to provide temporary liquidity funding to banks following resolution. The credibility of the resolution framework in Europe would be significantly enhanced by setting up a framework for liquidity in resolution.

    Moreover, building on the strong foundations of the SSM and the Single Resolution Mechanism, we must pave the way for a common European deposit insurance scheme (EDIS). In the first decade of the SSM, risks have been significantly reduced and common supervisory standards have been established. These preconditions for EDIS have now been met, and moving it forward will be important for severing any remaining feedback loops between banks and sovereigns, given that these proved so harmful during the sovereign debt crisis.

    Conclusion

    Let me conclude.

    Ten years ago today, when European supervisory teams started to come together for the first time, it was not at all certain that the SSM would be a success.

    We have since built a strong and effective supervisory framework in Europe, perceptive to evolving risks and – whenever necessary and appropriate – insistent in making sure that material risks are addressed. European banks have notably improved, proving resilient to shocks that we couldn’t have imagined a decade ago. This resilience is also a result of the strengthened supervisory and regulatory framework put in place after the global financial crisis, including the creation of the banking union.

    Ten years ago, the first Vice-Chair of the SSM, Sabine Lautenschläger, invoked the parallel of an athlete at the beginning of a career, who trained extremely hard and achieved an excellent result in a first major tournament.[15] To turn this promising start into a track record of sustained high performance, the athlete clearly cannot afford to rest on her laurels. Instead, she needs to go right back to the routine of constant training, to keep developing her skills and thus continue to build the foundation for future success on a day-to-day basis.

    This conclusion is as relevant today as it was ten year ago, especially considering the challenges along the path ahead.

    Considering the macro-financial environment and volatile risk landscape, it is safe to say that there is a high likelihood of unprecedented shocks continuing to emerge over the next decade. To make sure banks continue to serve European households and businesses under these challenging circumstances, we must ensure they remain resilient. Because a stable banking system forms the bedrock of long-term competitiveness and sustainable growth.

    European supervisors will continue to work tirelessly to make sure banks are well capitalised and adequately manage their risks. In this way, in ten years’ time we can celebrate another successful decade of resilient banks under European supervision.

    MIL OSI Europe News

  • MIL-OSI Canada: Prime Minister Justin Trudeau speaks with President of Ukraine Volodymyr Zelenskyy

    Source: Government of Canada – Prime Minister

    Today, Prime Minister Justin Trudeau spoke with the President of Ukraine, Volodymyr Zelenskyy.

    The leaders discussed the situation on the ground, and Prime Minister Trudeau reaffirmed Canada’s commitment to providing military, financial, humanitarian, and other support to Ukraine until it achieves victory against Russia’s unjustifiable war of aggression.

    Prime Minister Trudeau reaffirmed Canada’s support for President Zelenskyy’s ongoing diplomatic efforts toward a just and sustainable peace. The two leaders also discussed Ukraine’s victory plan, and the Prime Minister conveyed Canada’s support for the plan’s objectives.

    The leaders condemned North Korea’s troop deployment to support Russia’s ongoing war of aggression against Ukraine.

    The Prime Minister and the President noted the success of the Ministerial Conference on the Human Dimension of Ukraine’s 10-Point Peace Formula, which was held last week in Montréal, Quebec. They highlighted the efforts made at the Conference to help return deported children, unlawfully detained civilians, and prisoners of war currently held by Russia, as well as to reintegrate them back into their daily lives in Ukraine.

    The leaders agreed to remain in close and regular contact.

    Associated Links

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