Oil & Gas Product News Logo

TransCanada reports record third quarter financial results

TransCanada reports record third quarter financial results

Company info

450 - 1 Street SW
Calgary, AB
CA, T2P 5H1

Website:
transcanada.com

Read more

TransCanada Corporation announced net income attributable to common shares for third quarter 2018 of $928 million or $1.02 per share compared to net income of $612 million or $0.70 per share for the same period in 2017. Comparable earnings for third quarter 2018 were $902 million or $1.00 per share compared to $614 million or $0.70 per share for the same period in 2017. TransCanada's Board of Directors also declared a quarterly dividend of $0.69 per common share for the quarter ending December 31, 2018, equivalent to $2.76 per common share on an annualized basis.

"During the third quarter of 2018, our diversified portfolio of critical energy infrastructure assets continued to perform extremely well," said Russ Girling, TransCanada's president and chief executive officer. "Comparable earnings of $1.00 per share increased 43 per cent compared to the same period last year reflecting the strong performance of our legacy assets, contributions from approximately $7 billion of growth projects that entered service over the last twelve months and the positive impact of U.S. Tax Reform. For the nine months ended September 30, 2018, comparable earnings were $2.82 per share, an increase of 24 per cent over the same period last year despite the sale of our U.S. Northeast power generation and Ontario solar assets in 2017 and necessary financing activities that have us on track to return to long-term targeted credit metrics post the Columbia acquisition."

"With our existing asset portfolio benefiting from strong underlying market fundamentals and approximately $36 billion of secured growth projects underway including Coastal GasLink, NGTL's 2022 expansion program and Bruce Power's Unit 6 refurbishment, earnings and cash flow are forecast to continue to rise. This is expected to support annual dividend growth of eight to ten per cent through 2021," added Girling. "With approximately $10 billion of new projects expected to enter service by early 2019, we are well positioned to fund the remainder of our secured growth program through internally generated cash flow, access to capital markets and further portfolio management activities. Through the end of October, we placed approximately $6.1 billion of long-term debt on compelling terms and raised approximately $2.0 billion of common equity through our dividend reinvestment plan and at-the-market program. We also completed the sale of our interests in the Cartier Wind power facilities for proceeds of approximately $630 million and expect to be reimbursed for approximately $400 million of Coastal GasLink pre-development costs. Collectively these initiatives have raised $9.1 billion which, when combined with our growing internally generated cash flow, means our 2018 financing requirements are fully funded. We view ATM issuance as being complete at this time while our dividend reinvestment plan will operate for some portion of 2019. Going forward, we will continue to evaluate share count growth against further portfolio management activities."

"Looking ahead, we continue to methodically advance more than $20 billion of projects under development including Keystone XL and the Bruce Power life extension agreement. Success in advancing these and/or other growth initiatives associated with our vast, well-positioned North American footprint could extend our growth outlook well into the next decade," concluded Girling.

Highlights(All financial figures are unaudited and in Canadian dollars unless noted otherwise)

  • Third quarter 2018 financial results
  • Net income attributable to common shares of $928 million or $1.02 per common share
  • Comparable earnings of $902 million or $1.00 per common share
  • Comparable earnings before interest, taxes, depreciation and amortization of $2.1 billion
  • Net cash provided by operations of $1.3 billion
  • Comparable funds generated from operations of $1.6 billion
  • Comparable distributable cash flow of $1.4 billion or $1.56 per common share reflecting only non-recoverable maintenance capital expenditures
  • Declared a quarterly dividend of $0.69 per common share for the quarter ending December 31, 2018
  • Announced that we will proceed with construction of the $6.2 billion Coastal GasLink pipeline project
  • Announced $1.5 billion NGTL 2022 Expansion Program 
  • Bruce Power submitted a final estimate for the Unit 6 Major Component Replacement (MCR) program to the Independent Electricity System Operator (IESO) in September 2018; we expect to invest approximately $2.2 billion in this and the ongoing Asset Management program through 2023
  • Issued $1.0 billion of 10- and 30-year fixed-rate medium-term notes in July 2018
  • Raised US$1.4 billion of 10- and 30-year fixed-rate senior notes in October 2018
  • Completed the sale of our interests in Cartier Wind for approximately $630 million in October 2018
  • Expect to be reimbursed for $399 million of Coastal GasLink pre-development costs in fourth quarter 2018.

Net income attributable to common shares increased by $316 million or $0.32 per common share to $928 million or $1.02 per share for the three months ended September 30, 2018 compared to the same period last year. Per share results in 2018 reflect the dilutive effect of common shares issued in 2017 and 2018 under our DRP and Corporate ATM program. Third quarter 2018 results included after-tax income of $8 million related to our U.S. Northeast power marketing contracts which were excluded from comparable earnings as we do not consider their wind-down part of our underlying operations. Third quarter 2017 results included a $12 million after-tax loss related to the monetization of our U.S. Northeast power generation assets, an after-tax charge of $30 million for integration-related costs associated with the acquisition of Columbia and an after-tax charge of $8 million related to the maintenance of Keystone XL assets. All of these specific items, as well as unrealized gains and losses from changes in risk management activities, are excluded from comparable earnings.

Comparable earnings for third quarter 2018 were $902 million or $1.00 per common share compared to $614 million or $0.70 per common share for the same period in 2017, an increase of $288 million or $0.30 per share and was primarily due to the net effect of:

  • higher contribution from U.S. Natural Gas Pipelines mainly due to increased earnings from Columbia Gas and Columbia Gulf growth projects placed in service, additional contract sales on ANR and Great Lakes and the amortization of net regulatory liabilities recognized as a result of U.S. Tax Reform
  • higher contribution from Liquids Pipelines primarily due to earnings from intra-Alberta pipelines placed in service in the second half of 2017, increased earnings from liquids marketing activities, and higher volumes on the Keystone Pipeline System
  • lower income tax expense primarily due to lower income tax rates as a result of U.S. Tax Reform
  • higher revenues from our Mexico operations as a result of changes in timing of revenue recognition
  • higher interest expense primarily as a result of long-term debt and junior subordinated notes issuances, net of maturities, and lower capitalized interest.

Notable recent developments include:

Canadian Natural Gas Pipelines:

  • Coastal GasLink Pipeline (CGL) Project: On October 2, 2018, we announced that we will proceed with construction of the CGL pipeline project following the LNG Canada joint venture participants' announcement that they have reached a positive Final Investment Decision (FID) to build the LNG Canada natural gas liquefaction facility in Kitimat, BC. CGL will provide the natural gas supply to the LNG Canada facility and is underpinned by 25-year transportation services agreements (with additional renewal provisions) with the LNG Canada participants. CGL is a 670 km (420 miles) pipeline with an initial capacity of approximately 2.2 PJ/d (2.1 Bcf/d) with potential expansion capacity up to 5.4 PJ/d (5.0 Bcf/d). All necessary regulatory permits have been received to allow us to proceed with construction activities which are expected to begin in January 2019, with a planned in-service date in 2023. CGL has signed project and community agreements with all 20 elected Indigenous bands along the pipeline route, confirming strong support from Indigenous communities across the province of B.C.On July 30, 2018, an individual asked the National Energy Board (NEB) to consider whether the CGL pipeline should be federally regulated by the NEB. On October 22, 2018 the NEB advised that it would consider the question of jurisdiction. In the same letter, the NEB set a process to determine whether the individual who raised the question has standing, and to decide on the standing of any other interested parties. The process to consider the jurisdictional question is to be determined and the permits to construct remain valid.The capital cost estimate is $6.2 billion with the majority of the construction spend occurring in 2020 and 2021. Subject to terms and conditions, differences between the estimated capital cost and final cost of the project will be recovered in future pipeline tolls.  As part of the CGL funding plan, we intend to explore joint venture partners and project financing for the project.The total capital cost estimate includes pre-development costs to date of approximately $470 million. In accordance with provisions in the agreements with the LNG Canada joint venture participants, to date, four parties have elected to reimburse us for their share of pre-development costs, totaling $399 million of cost reimbursement, with payments due by November 30, 2018.
  • NGTL System: On October 31, 2018, we announced the NGTL 2022 Expansion Program to meet capacity requirements for incremental firm receipt and intra-basin delivery services to commence in November 2021 and April 2022. This $1.5 billion expansion of the NGTL System consists of approximately 197 km (122 miles) of new pipeline, three compressor units, meter stations and associated facilities. Applications for approvals to construct and operate the facilities are expected to be filed with the NEB in second quarter 2019 and, pending receipt of regulatory approvals, construction would start as early as third quarter 2020. The NGTL capital program, excluding maintenance capital expenditures, is now approximately $9.1 billion including the $1.5 billion 2022 Expansion Program.
  • Canadian Mainline: On October 9, 2018, we concluded the written hearing process for the Canadian Mainline 2018-2020 toll review with the filing of our reply evidence to the NEB. We have requested a decision by December 31, 2018.

U.S. Natural Gas Pipelines:

  • WB XPress: The Western Build of the WB XPress (WBX) project was placed into service on October 5, 2018. The Eastern Build of WBX remains to be completed, as planned, in fourth quarter 2018.
  • 2018 FERC Actions: On March 15, 2018, the Federal Energy Regulatory Commission (FERC) issued (1) a  Revised Policy Statement to address the treatment of income taxes for rate-making purposes for master limited partnerships; (2) a Notice of Proposed Rulemaking (NOPR) proposing natural gas pipeline and storage entities file a one-time report to quantify the impact of the federal income tax rate reduction and the impact of the Revised Policy Statement on each entity's return on equity assuming a single-issue adjustment to an entity's rates; and (3) a notice of inquiry seeking comment on how FERC should address changes related to accumulated deferred income taxes and bonus depreciation. On July 18, 2018, FERC issued (1) an Order on Rehearing of the Revised Policy Statement dismissing rehearing requests and (2) a Final Rule adopting and revising procedures from, and clarifying aspects of, the NOPR (Final Rule), (collectively, the "2018 FERC Actions"). The Final Rule became effective September 13, 2018, and is subject to requests for further rehearing and clarification. Each is described more fully in our management's discussion and analysis (MD&A).Our U.S. natural gas pipelines are held through a number of different ownership structures. We do not anticipate that the earnings and cash flows from our directly-held U.S. natural gas pipelines, including ANR, Columbia Gas and Columbia Gulf, will be materially impacted by the Revised Policy Statement as a significant proportion of their overall revenues are earned under non-recourse rates.For more information on the impact of the 2018 FERC Actions on TC PipeLines, LP and our U.S. natural gas pipelines held through TC PipeLines, LP, please refer to our MD&A in the 2018 FERC Actions section. As our ownership interest in TC PipeLines, LP is approximately 25 per cent, the impact of the 2018 FERC Actions related to TC PipeLines, LP is not expected to be significant to our consolidated earnings or cash flows.
  • Rate Settlements: In October 2018, Gas Transmission Northwest LLC (GTN) filed with FERC an uncontested settlement with its customers. Please refer to our MD&A in the 2018 FERC Actions section for additional detail.

Mexico Natural Gas Pipelines:

  • Sur de Texas: Offshore construction was completed in May 2018 and the project continues to progress toward an anticipated in-service date at the end of 2018. An amending agreement has been signed with the Comisión Federal de Electricidad (CFE) that recognizes force majeure events and the commencement of payments of fixed capacity charges beginning October 31, 2018.
  • Tula and Villa de Reyes: The CFE has approved the recognition of force majeure events for both of these pipelines, including the continuation of the payment of fixed capacity charges to us that began in first quarter 2018. Construction of the Villa de Reyes project is ongoing and it is anticipated to be in service by the second half of 2019.

Liquids Pipelines:

  • Keystone XL: In December 2017, an appeal to Nebraska's Court of Appeals was filed by intervenors after the Nebraska Public Service Commission (PSC) issued an approval of an alternative route for the Keystone XL project in November 2017. In March 2018, the Nebraska Supreme Court, on its own motion, agreed to bypass the Court of Appeals and directly hear the appeal case against the PSC's alternative route. Legal briefs on the appeal were submitted in May 2018. Oral argument before the Nebraska Supreme Court has been set for November 1, 2018. We expect the Nebraska Supreme Court, as the final arbiter, could reach a decision by first quarter 2019.The Keystone XL Presidential Permit, issued in March 2017, has been challenged in two separate lawsuits commenced in Montana. Together with the U.S. Department of Justice (DOJ), we are actively participating in these lawsuits to defend both the issuance of the permit and the exhaustive environmental assessments that support the U.S. President's actions. Legal arguments addressing the merits of these lawsuits were heard in May 2018 and we believe the court's decisions on certain elements of these legal challenges may be issued by the end of 2018.On August 15, 2018, the U.S. District Court in Montana issued a Partial Order requiring the DOJ and the U.S. Department of State (DOS) (the Federal Defendants) to prepare a supplemental environmental impact statement (SEIS) to the 2014 Final Supplemental Environmental Impact Statement and a proposed schedule for the completion of the SEIS. On September 4, 2018, the Federal Defendants responded to this Partial Order by filing the required schedule which reflected the issuance of the final SEIS in December 2018. On September 21, 2018, the DOS issued a draft SEIS which concluded that implementation of the mainline alternative route would have no significant direct, indirect or cumulative effect on the quality of the natural or human environments, having consideration for the mitigation plans proposed by TransCanada. The draft SEIS is open for public comment for a period of 45 days. The Federal Defendants also indicated that the U.S. Bureau of Land Management and the U.S. Army Corps of Engineers would likely issue decisions regarding their respective federal permitting activities in first quarter 2019.In September 2018, two U.S. Native American communities filed a lawsuit in Montana challenging the Keystone XL Presidential Permit. It is uncertain how and when this lawsuit will proceed.

Energy:

  • Cartier Wind: On October 24, 2018, we completed the sale of our interests in the Cartier Wind power facilities in Québec to Innergex Renewable Energy Inc. for gross proceeds of approximately $630 million before closing adjustments resulting in an estimated gain of $170 million ($135 million after tax) to be recorded in fourth quarter 2018.
  • Bruce Power - Life Extension: On September 28, 2018, Bruce Power submitted its final cost and schedule duration estimate (basis of estimate) for the Unit 6 MCR program to the IESO. The IESO has up to three months to review and verify the basis of estimate. As the cost and schedule duration are both less than the thresholds defined in the program's life extension and refurbishment agreement, no further approvals from the IESO or government are required to proceed with the Unit 6 MCR outage in early 2020. The Unit 6 MCR outage is expected to be completed in late 2023.As a result of this filing, we have updated our project cost estimates in our Capital Program tables to reflect our expected investment of approximately $2.2 billion (in nominal dollars) in Bruce Power's Unit 6 MCR program and ongoing Asset Management (AM) program through 2023, and approximately $6.0 billion (in 2018 dollars) for the remaining five-unit MCR program and the AM program beyond 2023. Future MCR investments will be subject to discrete decisions for each unit with specified off-ramps available for Bruce Power and the IESO.Bruce Power's current contract price of approximately $68 per MWh will be increased in April 2019 to reflect capital to be invested under the Unit 6 MCR program and the AM program as well as normal annual inflation adjustments.
  • Napanee: Construction continues on our 900 MW natural gas-fired power plant at Ontario Power Generation's (OPG) Lennox site in eastern Ontario in the town of Greater Napanee. We expect our total investment in the Napanee facility will be approximately $1.6 billion and commercial operations are expected to begin in first quarter 2019. Costs have increased due to delays in the construction schedule. Once in service, production from the facility is fully contracted with the IESO for a 20-year period.

Corporate:

  • Common Share Dividend: Our Board of Directors declared a quarterly dividend of $0.69 per share for the quarter ending December 31, 2018 on TransCanada's outstanding common shares. The quarterly amount is equivalent to $2.76 per common share on an annualized basis.
  • Issuance of Long-term Debt: In October 2018, TCPL issued US$1.0 billion of Senior Unsecured Notes due in March 2049 bearing interest at a fixed rate of 5.10 per cent and US$400 million of Senior Unsecured Notes due in May 2028 bearing interest at a fixed rate of 4.25 per cent.In third quarter 2018, TCPL issued $800 million of Medium Term Notes due in July 2048 bearing interest at a fixed rate of 4.18 per cent and $200 million of Medium Term Notes due in March 2028 bearing interest at a fixed rate of 3.39 per cent.The net proceeds of the above debt issuances were used for general corporate purposes, to fund our capital program and to pre-fund 2019 senior note maturities.In third quarter 2018, TCPL repaid US$850 million of Senior Unsecured Notes bearing interest at a fixed rate of 6.50 per cent.
  • Dividend Reinvestment Plan: In third quarter 2018, the DRP participation rate amongst common shareholders was approximately 34 per cent, resulting in $213 million reinvested in common equity under the program. Year-to-date in 2018, the participation rate amongst common shareholders has been approximately 35 per cent, resulting in $655 million of dividends reinvested.
  • ATM Equity Program: In third quarter 2018, 6.1 million common shares were issued under our Corporate ATM program at an average price of $57.75 per common share for proceeds of $351 million, net of related commissions and fees of approximately $3 million. In the nine months ended September 30, 2018, 20.0 million common shares have been issued under our Corporate ATM program at an average price of $56.13 per common share for proceeds of $1.1 billion, net of approximately $10 million of related commissions and fees.

Management's discussion and analysis

October 31, 2018

This management's discussion and analysis (MD&A) contains information to help the reader make investment decisions about TransCanada Corporation. It discusses our business, operations, financial position, risks and other factors for the three and nine months ended September 30, 2018, and should be read with the accompanying unaudited condensed consolidated financial statements for the three and nine months ended September 30, 2018, which have been prepared in accordance with U.S. GAAP.

This MD&A should also be read in conjunction with our December 31, 2017 audited consolidated financial statements and notes and the MD&A in our 2017 Annual Report. Capitalized and abbreviated terms that are used but not otherwise defined herein are identified in our 2017 Annual Report. Certain comparative figures have been adjusted to reflect the current period's presentation.

FORWARD-LOOKING INFORMATION We disclose forward-looking information to help current and potential investors understand management's assessment of our future plans and financial outlook, and our future prospects overall.

Statements that are forward-looking are based on certain assumptions and on what we know and expect today. These statements generally include words like anticipate, expect, believe, may, will, should, estimate or other similar words.

Forward-looking statements in this MD&A include information about the following, among other things:

  • planned changes in our business
  • our financial and operational performance, including the performance of our subsidiaries
  • expectations or projections about strategies and goals for growth and expansion
  • expected cash flows and future financing options available to us
  • expected dividend growth
  • expected costs for planned projects, including projects under construction, permitting and in development
  • expected schedules for planned projects (including anticipated construction and completion dates)
  • expected regulatory processes and outcomes, including the expected impact of the 2018 FERC Actions
  • expected outcomes with respect to legal proceedings, including arbitration and insurance claims
  • expected capital expenditures and contractual obligations
  • expected operating and financial results
  • expected impact of future accounting changes, commitments and contingent liabilities
  • expected impact of U.S. Tax Reform
  • expected industry, market and economic conditions.

Forward-looking statements do not guarantee future performance. Actual events and results could be significantly different because of assumptions, risks or uncertainties related to our business or events that happen after the date of this MD&A.

Our forward-looking information is based on the following key assumptions, and is subject to the following risks and uncertainties:

Assumptions

  • continued wind-down of our U.S. Northeast power marketing business
  • inflation rates and commodity prices
  • nature and scope of hedging activities
  • regulatory decisions and outcomes, including those related to the 2018 FERC Actions
  • interest, tax and foreign exchange rates, including the impact of U.S. Tax Reform
  • planned and unplanned outages and the use of our pipeline and energy assets
  • integrity and reliability of our assets
  • access to capital markets
  • anticipated construction costs, schedules and completion dates.

Risks and uncertainties

  • our ability to successfully implement our strategic priorities and whether they will yield the expected benefits
  • the operating performance of our pipeline and energy assets
  • amount of capacity sold and rates achieved in our pipeline businesses
  • the availability and price of energy commodities
  • the amount of capacity payments and revenues from our energy business
  • regulatory decisions and outcomes, including those related to the 2018 FERC Actions
  • outcomes of legal proceedings, including arbitration and insurance claims
  • performance and credit risk of our counterparties
  • changes in market commodity prices
  • changes in the regulatory environment
  • changes in the political environment
  • changes in environmental and other laws and regulations
  • competitive factors in the pipeline and energy sectors
  • construction and completion of capital projects
  • costs for labour, equipment and materials
  • access to capital markets
  • interest, tax and foreign exchange rates, including the impact of U.S. Tax Reform
  • weather
  • cyber security
  • technological developments
  • economic conditions in North America as well as globally.

You can read more about these factors and others in this MD&A and in other disclosure documents we have filed with Canadian securities regulators and the SEC, including the MD&A in our 2017 Annual Report.

As actual results could vary significantly from the forward-looking information, you should not put undue reliance on forward-looking information and should not use future-oriented information or financial outlooks for anything other than their intended purpose. We do not update our forward-looking statements due to new information or future events, unless we are required to by law.

FOR MORE INFORMATION You can find more information about TransCanada in our Annual Information Form and other disclosure documents, which are available on SEDAR (www.sedar.com).

NON-GAAP MEASURES This MD&A references the following non-GAAP measures:

  • comparable earnings
  • comparable earnings per common share
  • comparable EBITDA
  • comparable EBIT
  • funds generated from operations
  • comparable funds generated from operations
  • comparable distributable cash flow
  • comparable distributable cash flow per common share.

These measures do not have any standardized meaning as prescribed by GAAP and therefore may not be similar to measures presented by other entities.

Comparable measures We calculate comparable measures by adjusting certain GAAP and non-GAAP measures for specific items we believe are significant but not reflective of our underlying operations in the period. Except as otherwise described herein, these comparable measures are calculated on a consistent basis from period to period and are adjusted for specific items in each period, as applicable.

Our decision not to adjust for a specific item is subjective and made after careful consideration. Specific items may include:

  • certain fair value adjustments relating to risk management activities
  • income tax refunds and adjustments and changes to enacted tax rates
  • gains or losses on sales of assets or assets held for sale
  • legal, contractual and bankruptcy settlements
  • impact of regulatory or arbitration decisions relating to prior year earnings
  • restructuring costs
  • impairment of property, plant and equipment, goodwill, investments and other assets including certain ongoing maintenance and liquidation costs
  • acquisition and integration costs.

We exclude the unrealized gains and losses from changes in the fair value of derivatives used to reduce our exposure to certain financial and commodity price risks. These derivatives generally provide effective economic hedges but do not meet the criteria for hedge accounting. As a result, the changes in fair value are recorded in net income. As these amounts do not accurately reflect the gains and losses that will be realized at settlement, we do not consider them reflective of our underlying operations.

More from Industry News

Diversification pays off for Vertex Group entering 2019

Vertex Resource Group Ltd. reports its financial and operational results for the fourth quarter and year ending December 31, 2018. The results for the three months and year ending December 31, 2018 were highlighted by improvements in revenue, gross profit, EBITDA and net income as compared to the corresponding periods of 2017. Net income increased as a result of improved EBITDA and the bargain purchase gain from the three acquisitions completed in 2018 (which are discussed in more details in the MD&A and the Company's Annual Information Form filed on SEDAR at www.sedar.com), offset by increases in amortization and finance costs.

Inductive, contactless linear position sensor from Alliance Sensors Group

H. G. Schaevitz LLC, Alliance Sensors Group has released its LV-45 series inductive, contactless linear position sensor using LVIT Technology. The LV-45 linear position sensors are specifically designed for measuring applications requiring rugged devices, whether measuring position of steam turbine valves, mounted in a paper mill head box or calendar roll stand, or outdoors fastened to a building, bridge or structure. The LV-45 series was designed after identifying the wants and needs of engineers in the industrial world, so LV-45 Series linear position sensors can withstand the high vibration and severe shock environment found in steel, aluminum, and paper mills, as well as extremes of temperature and humidity found in most outdoor applications where many other types of linear position sensors cannot survive.

AltaGas founder and chair to step down after 25 years

AltaGas Ltd. (AltaGas) has announced  that after careful consideration, David Cornhill, Founder of AltaGas and Chairman, has elected to step down on April 1, 2019 from the Chairman position. New Chair Pentti Karkkainen has been appointed by the Board of Directors, effective April 2. Mr. Cornhill will remain on the Board, ensuring an orderly transition and continuity. 

Texas LNG project receives environmental impact statement from FERC

The United States Federal Energy Regulatory Commission has issued the Final Environmental Impact Statement for Texas LNG Brownsville LLC's proposed 2 train, 4 million tonnes per annum LNG export facility located in the Port of Brownsville, Texas. The FEIS has been issued in accordance with the anticipated dates listed in the Notice of Schedule for Environmental Review received in August 2018.

Fluor successfully completes EPC work on Sasol petrochemical complex

Fluor Corporation announced that its joint venture with TechnipFMC has successfully completed its engineering, procurement and construction management services scope of work on Sasol's world-scale petrochemical complex in Westlake, Louisiana. The joint venture will continue to provide assistance to the Sasol team with remaining activities by working with Sasol in parallel on transition plans for each unit and system. The joint venture team will also assist in performance testing for the complex.

Schneider Electric partners with Vericlave to strengthen customers' cyber posture

Schneider Electric, the leader in the digital transformation of energy management and automation, has entered into a global partnership with Vericlave, a leading cybersecurity technology provider. Under the terms of the agreement, Schneider Electric will provide Vericlave's advanced encryption technology to further secure and protect its customers' critical IT and OT systems from the risk of cyberattack.

free-paper-airplane

Get our newsletter

Learn more

NACE International launches enhanced new website to serve members and customers

NACE International, the nonprofit association and leading resource for corrosion expertise and education, has launched its newly redesigned website, www.nace.org. Based on feedback from frequent users and customers, the new site features enhanced tools and search functions, intuitive navigation to help users quickly locate information, and convenient mobile functionality and responsive design.

Sproule launches new Canadian NGL Report

Sproule and GTI have announced a strategic partnership to deliver a jointly developed Canadian natural gas liquids (NGL) report to industry. The report provides an in-depth understanding of the economics of producing natural gas and NGLs. This monthly report leverages the expertise of GTI and Sproule principals to provide insight and analysis on the profitability of natural gas and NGL production at western Canadian gas plants. Included in the report are supply and price forecasts for gas and NGLs, netback analysis by component and a summary of the market dynamics that are affecting pricing along commentary regarding key developments and relevant news. 

New United Electric Controls gas detector offers carbon monoxide monitoring and flexible mounting

United Electric Controls, a producer of safety, alarm and shutdown technology, has announced that it has added carbon monoxide (CO) to the list of gases detected by the latest Vanguard WirelessHART gas detector.  Vanguard version 1.2 also includes new mounting flexibility and a variety of other features that enhance installation, configurability and maintainability.

free-magazine-subscription

Get Our Magazine

Paper or Digital delivered monthly to you

Subscribe or Renew Learn more

Methane emission tracking needs innovative approach, study recommends

Tracking and reducing methane emissions from oil and gas operations needs an innovative approach, according to new report from the C.D. Howe Institute. In "Measuring and Managing the Unknown: Methane Emissions from the Oil and Gas Value Chain" authors Sarah Marie Jordaan and Kate Konschnik highlight the growing pressure on industry and policymakers to address the "unknown" factor in greenhouse gas emissions and propose a regulatory approach that remains open to new technologies.

Schneider Electric joins cybersecurity coalition to affirm role in strengthening digital trust

Dedicated to securing and protecting trust in the digital economy, Schneider Electric today announced its membership in the Cybersecurity Coalition, based in Washington, D.C. As a digital transformation leader operating in more than 100 countries, Schneider Electric continues to work closely with governments, customers, and partners to play a principal role in confronting cybersecurity risks and challenges. By joining the Coalition, Schneider affirms its commitment to being open, transparent, and collaborative so it can better detect, prevent, and respond to cyber threats across its extended enterprise.

Large diameter flex-hone plays critical role in oil and gas industry

In the oil and gas industry, failing to perform ongoing maintenance on equipment can have severe consequences including reducing equipment service life, causing unplanned shutdowns and degrading performance.  Ongoing maintenance is required to remove rust, corrosion and other accumulated material from the inside diameter (ID) of valves, pumps, piping, diesel engines, motors, natural gas compressors, flow meters and other large bore equipment.  Often, this maintenance work is performed in the field under harsh conditions.  

Pembina Pipeline Corporation launches new partnership with Ducks Unlimited Canada

A landmark gift from Pembina Pipeline Corporation is ensuring working landscapes across the Canadian Prairies also work for conservation. Its $1-million investment in Ducks Unlimited Canada's (DUC) Revolving Land Conservation Program will protect approximately 2,000 acres (809 hectares) of important wetland habitat. At the same time, communities across Alberta and Saskatchewan will profit from a host of environmental benefits. 

free-paper-airplane

Get our newsletter

Learn more

Uncooled methane gas detection camera from FLIR scales up LDAR programs

FLIR Systems, Inc. has launched the FLIR GF77 Gas Find IR, its first uncooled thermal camera designed for detecting methane. This handheld camera offers inspection professionals the features they need to find potentially dangerous, invisible methane leaks at natural gas power plants, renewable energy production facilities, industrial plants, and other locations along a natural gas supply chain. The GF77 provides methane gas detection capability at roughly half the price of cooled gas inspection thermal cameras, to empower the oil and gas industry to reduce emissions and ensure a safer work environment.

Perkins opens third Regional Logistics Centre in Curitiba, Brazil, to serve South and Central America

Perkins has announced the planned opening of a new Regional Logistics Centre (RLC) in Curitiba, Brazil, to support Original Equipment Manufacturers (OEMs) and Perkins distributors in South and Central America. Co-located with the Perkins engine manufacturing facility in Curitiba, the new RLC - expected to be operational in the first quarter of 2019 - will stock more than 3,000 genuine Perkins parts and provide next day or two-day delivery for most of the region.

Pembina reports record annual results in 2018

Pembina Pipeline Corporation has announced its financial and operating results for the fourth quarter and full year 2018. Pembina delivered strong 2018 financial and operational results leading to record full year earnings and Adjusted EBITDA. These results were largely driven by the full-year contribution from assets included in the acquisition of Veresen Inc. in October 2017 and assets placed into service following a large-scale capital program, driving growing revenue volumes. Highlights for the fourth quarter and full year 2018 include:

  • Fourth quarter and full year earnings of $368 million and $1.3 billion, a 17 percent decrease and 45 percent increase, respectively, over the same periods in 2017;
  • Cash flow from operating activities of $674 million for the fourth quarter and $2.3 billion in 2018, increases of 29 percent and 49 percent, respectively, over the same periods in 2017. Adjusted cash flow from operating activities increased by nine percent and 54 percent to $543 million and $2.2 billion in the fourth quarter and full year 2018, respectively, compared to the same periods in 2017;
  • On a per share (basic) basis, cash flow from operating activities for the fourth quarter and full year 2018 increased by 28 percent and 26 percent, respectively, compared to the same periods in the prior year. On a per share (basic) basis, adjusted cash flow from operating activities for the fourth quarter increased eight percent and 31 percent for the full year compared to the same periods of the prior year;
  • Fourth quarter and full year operating margin of $800 million and $3.2 billion, were seven percent and 64 percent higher, respectively, than the same periods of the prior year; and
  • Fourth quarter and full year Adjusted EBITDA of $715 million and $2.8 billion, representing six percent and 67 percent increases, respectively, over the same periods in 2017.
free-magazine-subscription

Get Our Magazine

Paper or Digital delivered monthly to you

Subscribe or Renew Learn more