UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
  
 
FORM 6-K
 
 
REPORT OF FOREIGN PRIVATE ISSUER PURSUANT TO RULE 13a-16 OR 15d-16
UNDER THE SECURITIES EXCHANGE ACT OF 1934
 
 
For the month of November, 2021
 
 
Commission File Number:  001-35563
 
 
PEMBINA PIPELINE CORPORATION

(Name of registrant)
 
(Room #39-095) 4000, 585 8th Avenue S.W.
Calgary, Alberta T2P 1G1

(Address of principal executive offices)
 
Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.
 
o Form 20-F
x Form 40-F
 
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1): o
 
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7): o

SIGNATURES
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
PEMBINA PIPELINE CORPORATION
Date: November 4, 2021 By: /s/ J. Scott Burrows
Name: J. Scott Burrows
Title: Senior Vice President and Chief Financial Officer




Form 6-K Exhibit Index
 
Exhibit Number Document Description
99.1
99.2
99.3



REPORT TO SHAREHOLDERS
PEMBINACOLOURLOGOA19.JPG
Third Quarter 2021
MANAGEMENT'S DISCUSSION AND ANALYSIS
Table of Contents
2
3
7
18
22
23
24
26
27
30
32
33
36
37
Basis of Presentation
The following Management's Discussion and Analysis ("MD&A") of the financial and operating results of Pembina Pipeline Corporation ("Pembina" or the "Company") is dated November 4, 2021, and is supplementary to, and should be read in conjunction with, Pembina's unaudited condensed consolidated interim financial statements for the three and nine months ended September 30, 2021 ("Interim Financial Statements") as well as Pembina's audited consolidated annual financial statements ("Consolidated Financial Statements") and MD&A for the year ended December 31, 2020. All financial information has been prepared in accordance with IAS 34 Interim Financial Reporting and is expressed in Canadian dollars, unless otherwise noted. A description of Pembina's operating segments and additional information about Pembina is filed with Canadian and U.S. securities commissions, including quarterly and annual reports, annual information forms (filed with the U.S. Securities and Exchange Commission under Form 40-F) and management information circulars, which can be found online at www.sedar.com, www.sec.gov and through Pembina's website at www.pembina.com. Information contained in or otherwise accessible through Pembina's website does not form part of this MD&A and is not incorporated into this document by reference.
Abbreviations
For a list of abbreviations that may be used in this MD&A, refer to the "Abbreviations" section of this MD&A.

Non-GAAP Financial Measures
Pembina has identified certain financial measures that management believes provide meaningful information in assessing
Pembina's underlying performance. Readers are cautioned that
such financial measures do not have a standardized meaning
prescribed by International Financial Reporting Standards ("IFRS")
and therefore may not be comparable to similar measures
presented by other entities. Refer to the "Non-GAAP Measures"
section of this MD&A for a list and description, including
reconciliations to the most directly comparable GAAP measures, of
such non-GAAP measures.
Risk Factors and Forward-Looking Information
Management has identified the primary risk factors that could have a material impact on the financial results and operations of Pembina. Such risk factors are presented in Pembina's MD&A and Annual Information Form ("AIF") for the year ended December 31, 2020 and have been updated in the "Risk Factors" section of this MD&A, as necessary. The Company's financial and operational performance is potentially affected by a number of factors, including, but not limited to, the factors described within the "Forward-Looking Statements & Information" section of this MD&A. This MD&A contains forward-looking statements based on Pembina's current expectations, estimates, projections and assumptions. This information is provided to assist readers in understanding the Company's future plans and expectations and may not be appropriate for other purposes.
Pembina Pipeline Corporation Third Quarter 2021 1


1. ABOUT PEMBINA
Pembina is a leading transportation and midstream service provider that has been serving North America's energy industry for more than 65 years. Pembina owns an integrated system of pipelines that transport various hydrocarbon liquids and natural gas products produced primarily in western Canada. The Company also owns gas gathering and processing facilities; an oil and natural gas liquids infrastructure and logistics business; and is growing an export terminals business. Pembina's integrated assets and commercial operations along the majority of the hydrocarbon value chain allow it to offer a full spectrum of midstream and marketing services to the energy sector. Pembina is committed to identifying additional opportunities to connect hydrocarbon production to new demand locations through the development of infrastructure that would extend Pembina's service offering even further along the hydrocarbon value chain. These new developments will contribute to ensuring that hydrocarbons produced in the Western Canadian Sedimentary Basin and the other basins where Pembina operates can reach the highest value markets throughout the world.
Purpose of Pembina:
To be the leader in delivering integrated infrastructure solutions connecting global markets;
Customers choose us first for reliable and value-added services;
Investors receive sustainable industry-leading total returns;
Employees say we are the 'employer of choice' and value our safe, respectful, collaborative and fair work culture; and
Communities welcome us and recognize the net positive impact of our social and environmental commitment.
Inter Pipeline Arrangement
On June 1, 2021, Pembina announced that it had entered into an arrangement agreement with Inter Pipeline Ltd. ("Inter Pipeline"), pursuant to which Pembina proposed to acquire all of the issued and outstanding common shares of Inter Pipeline by way of a plan of arrangement under the Business Corporations Act (Alberta) (the "Inter Pipeline Arrangement"). Pursuant to the Inter Pipeline Arrangement, holders of Inter Pipeline common shares (other than dissenting holders of Inter Pipeline common shares) would have received 0.5 of a common share of Pembina for each common share of Inter Pipeline that they owned. On July 25, 2021, the arrangement agreement was terminated and Pembina received the termination fee of $350 million ("Arrangement Termination Payment").
2 Pembina Pipeline Corporation Third Quarter 2021


2. FINANCIAL & OPERATING OVERVIEW
Consolidated Financial Overview for the Three Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(3)
Change % Change
Infrastructure and other services revenue 756  744  12 
Product sales revenue 1,393  752  641  85 
Total revenue 2,149  1,496  653  44 
Net revenue(1)
961  849  112  13 
Gross profit
682  568  114  20 
Earnings
588  323  265  82 
Earnings per common share – basic and diluted (dollars)
1.01  0.52  0.49  94 
Cash flow from operating activities 913  434  479  110 
Cash flow from operating activities per common share – basic (dollars)(1)
1.66  0.78  0.88  113 
Adjusted cash flow from operating activities(1)
786  524  262  50 
Adjusted cash flow from operating activities per common share – basic (dollars)(1)
1.43  0.95  0.48  51 
Capital investments 209  174  35  20 
Adjusted EBITDA(1)
850  796  54 
Total volumes (mboe/d)(2)
3,411  3,451  (40) (1)
Change in Earnings ($ millions)(3)(4)(5)
CHART-DCBB029AA3684131B36.JPG
Results Overview
Results in the third quarter of 2021 were positively impacted by higher gross profit in Marketing & New Ventures due to higher margins on NGL and crude oil sales, combined with higher marketed NGL volumes and higher share of profit from Aux Sable, partially offset by realized losses on commodity-related derivative financial instruments compared to realized gains in the third quarter of 2020. Facilities gross profit increased due to Prince Rupert Terminal, Empress Infrastructure and Duvernay III being placed into service, combined with unrealized gains for certain gas processing fees tied to AECO prices. Pipelines gross profit was impacted by revenues associated with higher volumes on the Peace Pipeline system, offset by a lower share of profit from Ruby, combined with the impact of a timing difference in the recognition of deferred revenue associated with the Cochin Pipeline and the impact of the lower U.S. dollar exchange rate. Other income increased due to the receipt of the Arrangement Termination Payment. General & administrative increased due to higher long-term incentive costs as a result of the change in Pembina's share price. Net finance costs increased during the third quarter of 2021 due to foreign exchanges losses compared to gains, of which the majority was recognized in the third quarter of 2020, while current tax expense increased as a result of higher current year earnings associated with the Arrangement Termination Payment.
Pembina Pipeline Corporation Third Quarter 2021 3


Changes in Results for the Three Months Ended September 30
Infrastructure and other services revenue
$12 million increase, due to higher volumes in Pipelines, assets placed into service in Facilities, and increased operating expense recoveries, partially offset by a timing difference in the recognition of deferred revenue associated with the Cochin Pipeline, discussed in the "Pipelines" section.
Product sales revenue
$641 million increase ($93 million increase net of cost of goods sold), largely due to higher NGL and crude oil market prices, combined with higher marketed NGL volumes.
Cost of goods sold
$541 million increase, largely due to higher NGL and crude oil market prices, combined with higher marketed NGL volumes, discussed above.
Operating expenses
$9 million increase, largely due to an increase in power costs, the majority of which are recoverable, as a result of the higher power pool price during the third quarter of 2021.
Depreciation and amortization included in operations
Consistent with the prior period.
Share of profit from equity accounted investees
$13 million increase, largely due to higher share of profit from Aux Sable as a result of higher NGL margins and a wider AECO-Chicago natural gas price differential and higher share of profit from Veresen Midstream from the Hythe Developments going into service in March 2021 and higher volumes at the Dawson Assets, partially offset by a lower contribution from Ruby.
Realized loss (gain) on commodity-related derivatives
$50 million negative variance, due to higher NGL market prices during the third quarter of 2021, which also drove higher margins on NGL sales, resulting in a realized loss on NGL-based derivative instruments for the period, compared to realized gains on NGL-based derivative instruments recognized during the third quarter of 2020. Pembina utilizes derivative instruments to stabilize the results of its marketing business.
Unrealized (gain) loss on commodity-related derivatives
$53 million positive variance, primarily due to the significant increase in the the AECO price during the period resulting in gains for certain gas processing fees tied to AECO prices, combined with contracts maturing in the period, partially offset by the increase in the forward prices for NGL and crude oil during the third quarter of 2021 and newly added contracts.
General & administrative
$12 million increase largely due to higher long-term incentives as a result of the change in Pembina's share price, combined with an increase in optimization project costs, partially offset by a reduction in salaries and wages.
Other income
$307 million increase primarily due to the $350 million Arrangement Termination Payment, partially offset by higher transformation and restructuring costs.
Net finance costs
$62 million increase, primarily driven by foreign exchange losses and higher interest expense associated with tax settlements, combined with losses on non-commodity-related derivative financial instruments compared to gains in the third quarter of 2020.
Current tax expense
$89 million increase, primarily due to higher current year earnings associated with the Arrangement Termination Payment, discussed above.
Deferred tax expense
Consistent with the prior period.
Cash flow from operating activities
$479 million increase, primarily driven by the $350 million Arrangement Termination Payment, discussed above, an increase in operating results after adjusting for non-cash items, combined with a $96 million change in non-cash working capital and a $21 million decrease in taxes paid, partially offset by a $12 million increase in net interest paid.
Adjusted cash flow from operating activities(1)
$262 million increase, largely due to the same items impacting cash flow from operating activities, discussed above, net of the change in non-cash working capital and decrease in taxes paid, partially offset by the $89 million higher current tax expense and $17 million increase in accrued share based payments.
Adjusted EBITDA(1)
$54 million increase, largely due to higher margins on NGL and crude oil sales, a higher contribution from Aux Sable, combined with the contributions from assets placed into service in Facilities, and higher volumes on the Peace Pipeline system, partially offset by the realized loss on commodity-related derivatives, lower contribution from Ruby due to lower contracted volumes, the impact of a timing difference in the recognition of deferred revenue associated with the Cochin Pipeline, and higher general and administrative expenses, discussed above. Included in adjusted EBITDA is $178 million (2020: $168 million) related to equity accounted investees.
Total volumes (mboe/d)(2)
40 mboe/d decrease, largely driven by lower volumes on the Ruby Pipeline, combined with lower volumes at the Redwater Complex and at Alberta Ethane Gathering System ("AEGS") following third party outages, and lower volumes at the Saturn Complex due to higher deferred revenue volumes recognized in the third quarter of 2020, partially offset by higher volumes on the Peace Pipeline system due to increased upstream activities, higher volumes at Younger due to a turnaround in the third quarter of 2020, and the contributions from assets placed into service in Facilities. Volumes include 298 mboe/d (2020: 310 mboe/d) related to equity accounted investees.
Increase; Decrease; or No impact; to earnings, adjusted EBITDA, cash flow from operations, adjusted cash flow from operating activities or total volumes.
(1)    Refer to the "Non-GAAP Measures" section.
(2)    Total revenue volumes. See the "Abbreviations" section for definition. Marketed NGL volumes are excluded from volumes to avoid double counting. Refer to the "Marketing & New Ventures" section for further information.
(3)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy", "Restatement of Revenue and Cost of Goods Sold" and Note 2 to the Interim Financial Statements.
(4)    Facilities results ex. commodity-related derivatives and Marketing & New Ventures results ex. commodity-related derivatives includes gross profit less realized and unrealized losses on commodity related derivative financial instruments.
(5)    Other includes other expenses, impairments and corporate.
4 Pembina Pipeline Corporation Third Quarter 2021


Consolidated Financial Overview for the Nine Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(3)
Change % Change
Infrastructure and other services revenue 2,240  2,199  41 
Product sales revenue 3,827  2,074  1,753  85 
Revenue 6,067  4,273  1,794  42 
Net revenue(1)
2,854  2,490  364  15 
Gross profit
1,862  1,761  101 
Earnings
1,162  900  262  29 
Earnings per common share – basic (dollars)
1.92  1.42  0.50  35 
Earnings per common share – diluted (dollars)
1.91  1.42  0.49  35 
Cash flow from operating activities 1,953  1,486  467  31 
Cash flow from operating activities per common share – basic (dollars)(1)
3.55  2.70  0.85  31 
Adjusted cash flow from operating activities(1)
1,906  1,686  220  13 
Adjusted cash flow from operating activities per common share – basic (dollars)(1)
3.47  3.07  0.40  13 
Capital investments 482  868  (386) (44)
Adjusted EBITDA(1)
2,463  2,415  48 
Total volumes (mboe/d)(2)
3,464  3,462  — 
Change in Earnings ($ millions)(3)(4)(5)
CHART-29E3B0A6A4CB4280A54.JPG
Results Overview
Results for the nine months ended September 30, 2021 were positively impacted by higher gross profit in Marketing & New Ventures due to higher margins on NGL and crude oil sales, combined with higher marketed NGL volumes and higher share of profit from Aux Sable, offset by losses on commodity-related derivative financial instruments. Facilities gross profit increased due to Prince Rupert Terminal, Empress Infrastructure and Duvernay III being placed into service, combined with unrealized gains for certain gas processing fees tied to AECO prices. In Pipelines, higher volumes were offset by lower share of profit from Ruby, combined with the impact of the lower U.S. dollar exchange rate. Other income increased due to the receipt of the Arrangement Termination Payment, offset by lower income received from the Canadian Emergency Wage Subsidy and higher transformation and restructuring related costs. General & administrative increased due to higher incentive costs primarily driven by the change in Pembina's share price. Income tax expense increased significantly as a result of higher current year earnings driven by the Arrangement Termination Payment.
Pembina Pipeline Corporation Third Quarter 2021 5


Changes in Results for the Nine Months Ended September 30
Infrastructure and other services revenue
$41 million increase, due to assets placed into service in Facilities and higher volumes in Pipelines, combined with higher operating expense recoveries as a result of higher power costs, partially offset by lower storage and rail terminal revenue, including fully recovered capital fees at the Edmonton South Rail Terminal and the impact of lower U.S. dollar exchange rates.
Product sales revenue
$1.8 billion increase ($296 million increase net of cost of goods sold), largely due to higher NGL and crude oil market prices, resulting in higher margins, combined with higher marketed NGL volumes as Pembina monetized a portion of its previously built up storage positions.
Cost of goods sold
$1.4 billion increase, largely due to higher NGL and crude oil market prices, combined with higher marketed NGL volumes.
Operating expenses
$44 million increase, largely due to an increase in power costs, the majority of which are recoverable, as a result of the higher power pool price during the first nine months of 2021, combined with higher operating expenses associated with the additional assets being placed into service in Facilities.
Depreciation and amortization included in operations
$22 million increase, primarily due to additional assets being placed into service during the first nine months of 2021.
Share of profit from equity accounted investees
$14 million decrease, largely due to a lower contribution from Ruby, combined with the impact of lower U.S. dollar exchange rates, partially offset by higher NGL margins and a wider AECO-Chicago natural gas price differential at Aux Sable and higher share of profit from Veresen Midstream due to the contributions from the Hythe Developments going into service in March 2021 and higher volumes at the Dawson Assets.
Realized loss (gain) on commodity-related derivatives
$224 million negative variance, due to higher NGL and crude oil market prices during the period, which also drove higher margins on NGL and crude sales, resulting in a realized loss on NGL and crude oil-based derivative instruments for the period, compared to realized gains recognized during the first nine months of 2020. Pembina utilizes derivative instruments to stabilize the results of its marketing business.
Unrealized gain on commodity-related derivatives
$41 million positive variance, primarily due to the significant increase in the the AECO price during the period resulting in gains for certain gas processing fees tied to AECO prices.
General & administrative
$58 million increase largely due to higher incentive costs primarily driven by the change in Pembina's share price, combined with an increase in optimization project costs, partially offset by a reduction in salaries and wages.
Other income
$275 million increase primarily due to the $350 million ($250 million net of tax and associated expenses) Arrangement Termination Payment, partially offset by lower income associated with Canadian Emergency Wage Subsidy and higher transformation and restructuring costs.
Net finance costs
$18 million decrease, primarily driven by foreign exchange gains in the period compared to foreign exchange losses in the first nine months of 2020 as a result of hedge accounting adopted in the second quarter of 2020, partially offset by higher interest expense associated with higher average debt levels.
Current tax expense
$60 million increase, primarily due to higher current year earnings associated with the Arrangement Termination Payment, discussed above.
Deferred tax expense
$21 million decrease, largely due to the release of final U.S. tax regulations in 2020, combined with the recovery on the impairment expense.
Cash flow from operating activities
$467 million increase, primarily driven by the $350 million Arrangement Termination Payment received in the third quarter of 2021, discussed above, an increase in operating results after adjusting for non-cash items, combined with a $98 million change in non-cash working capital and a $25 million decrease in taxes paid, partially offset by a $36 million increase in net interest paid and a $17 million decrease in distributions from equity accounted investees.
Adjusted cash flow from operating activities(1)
$220 million increase, largely due to the same items impacting cash flow from operating activities, discussed above, net of the change in non-cash working capital and decrease in taxes paid, partially offset by the $62 million higher accrued share-based payments and $60 million higher current tax expense.
Adjusted EBITDA(1)
$48 million increase, primarily due to higher margins on NGL and crude oil sales, combined with new assets placed into service in Facilities, higher volumes on the Peace Pipeline system, and a higher contribution from Aux Sable, partially offset by the realized loss on commodity-related derivatives, lower contribution from Ruby due to lower contracted volumes, higher general and administrative expenses and the impact of the lower U.S. dollar exchange rate. Included in adjusted EBITDA is $536 million (2020: $509 million) related to equity accounted investees.
Total volumes (mboe/d)(2)
Consistent with the prior period. Higher volumes in Pipelines due to increased upstream activities, combined with higher revenue volumes from assets placed into service in Facilities and higher seasonal volumes on the Alliance Pipeline, were largely offset by lower volumes at AEGS due to third-party outages in August 2021, combined with lower contracted volumes on the Ruby Pipeline. Volumes include 318 mboe/d (2020: 312 mboe/d) related to equity accounted investees.
Increase; Decrease; or No impact; to earnings, adjusted EBITDA, cash flow from operations, adjusted cash flow from operating activities or total volumes.
(1)    Refer to the "Non-GAAP Measures" section.
(2)    Total revenue volumes. See the "Abbreviations" section for definition. Marketed NGL volumes are excluded from volumes to avoid double counting. Refer to the "Marketing & New Ventures" section for further information.
(3)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy", "Restatement of Revenue and Cost of Goods Sold" and Note 2 to the Interim Financial Statements.
(4)    Facilities results ex. commodity-related derivatives and Marketing & New Ventures results ex. commodity-related derivatives includes gross profit less realized and unrealized losses on commodity related derivative financial instruments.
(5)    Other includes other expenses, impairments and corporate.

6 Pembina Pipeline Corporation Third Quarter 2021


3. SEGMENT RESULTS
Business Overview
The Pipelines Division provides customers with pipeline transportation, terminalling, storage and rail services in key market hubs in Canada and the United States for crude oil, condensate, natural gas liquids and natural gas. The division includes pipeline transportation capacity of approximately 3.1 mmboe/d(1) and above ground storage capacity of approximately 11 mmbbls(1) within its conventional, oil sands and heavy oil, and transmission assets. The conventional assets include strategically located pipelines and terminalling hubs that gather and transport light and medium crude oils, condensate and natural gas liquids from western Alberta and northeast British Columbia to the Edmonton, Alberta area for further processing or transportation on downstream pipelines. The oil sands and heavy oil assets transport heavy and synthetic crude oil produced within Alberta to the Edmonton area and offer associated storage, terminalling and rail services. The transmission assets transport natural gas, ethane and condensate throughout Canada and the United States on long haul pipelines linking various key market hubs. In addition, the Pipelines Division assets provide linkages between Pembina's upstream and downstream assets across North America, enabling integrated customer service offerings. Together, these assets supply product from hydrocarbon producing regions to refineries, fractionators and market hubs in Alberta, British Columbia, Illinois and California, as well as other regions throughout North America.
The Facilities Division includes infrastructure that provides Pembina's customers with natural gas, condensate and NGL services. Pembina's natural gas gathering and processing assets are strategically positioned in active, liquids-rich areas of the WCSB and Williston Basin and are integrated with the Company's other businesses. Pembina provides sweet and sour gas gathering, compression, condensate stabilization, and both shallow cut and deep cut gas processing services with a total capacity of approximately 6.1 bcf/d(2) for its customers. Condensate and NGL extracted at virtually all Canadian-based facilities have access to transportation on Pembina's pipelines. In addition, all NGL transported along the Alliance Pipeline are extracted through the Pembina-operated Channahon Facility at the terminus. The Facilities Division includes approximately 354 mbpd(2) of NGL fractionation capacity, 21 mmbbls(1) of cavern storage capacity, associated pipeline and rail terminalling facilities, and a liquefied propane export facility on Canada's West Coast. These facilities are fully integrated with the Company's other divisions, providing customers with the ability to access a comprehensive suite of services to enhance the value of their hydrocarbons. In addition, Pembina owns a bulk marine export terminal in Vancouver, British Columbia.
The Marketing & New Ventures Division strives to maximize the value of hydrocarbon liquids and natural gas originating in the basins where the Company operates. Pembina seeks to further enhance existing markets and create new markets, to support both the Company's and its customers' overall business interests. In particular, Pembina seeks to identify opportunities to connect hydrocarbon production to new demand locations through the development of infrastructure. Pembina strives to increase producer netbacks and product demand to improve the overall competitiveness of the basins where the Company operates. Within the Marketing & New Ventures Division, Pembina undertakes value-added commodity marketing activities including buying and selling products (natural gas, ethane, propane, butane, condensate and crude oil), commodity arbitrage, and optimizing storage opportunities. The marketing business enters into contracts for capacity on both Pembina's and third-party infrastructure, handles proprietary and customer volumes and aggregates production for onward sale.
(1)Net capacity; excludes projects under development.
(2)Net capacity. Includes Aux Sable capacity. The financial and operational results for Aux Sable are included in the Marketing & New Ventures Division; excludes projects under development.
Pembina Pipeline Corporation Third Quarter 2021 7


Financial and Operational Overview by Division
3 Months Ended September 30 9 Months Ended September 30
2021 2020 2021 2020
($ millions, except where noted)
Volumes(1)
Gross Profit
Adjusted EBITDA(2)
Volumes(1)
Gross Profit(4)
Adjusted EBITDA(2)
Volumes(1)
Gross Profit
Adjusted
EBITDA
(2)
Volumes(1)
Gross Profit(4)
Adjusted
EBITDA
(2)
Pipelines
2,563  347  503  2,580  381  541  2,592  1,047  1,554  2,588  1,159  1,631 
Facilities
848  233  273  871  182  251  872  628  812  874  523  757 
Marketing & New
Ventures(3)
  100  109  —  34    185  237  —  77  118 
Corporate
  2  (35) —  —  (30)   2  (140) —  (91)
Total 3,411  682  850  3,451  568  796  3,464  1,862  2,463  3,462  1,761  2,415 
(1)    Volumes for Pipelines and Facilities are revenue volumes, which are physical volumes plus volumes recognized from take-or-pay commitments. Volumes are stated in mboe/d, with natural gas volumes converted to mboe/d from MMcf/d at a 6:1 ratio.
(2)    Refer to the "Non-GAAP Measures" section.
(3)    Marketed NGL volumes are excluded from volumes to avoid double counting. Refer to the "Marketing & New Ventures" section for further information.
(4)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy" and Note 2 to the Interim Financial Statements.
8 Pembina Pipeline Corporation Third Quarter 2021


Pipelines
Financial Overview for the Three Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(4)
Change % Change
Conventional revenue(1)
360  323  37  11 
Transmission revenue(1)
97  120  (23) (19)
Oil Sands revenue(1)
109  114  (5) (4)
Pipelines revenue(1)
566  557 
Operating expenses(1)
140  129  11 
Share of profit from equity accounted investees 21  56  (35) (63)
Depreciation and amortization included in operations 100  103  (3) (3)
Gross profit 347  381  (34) (9)
Adjusted EBITDA(2)
503  541  (38) (7)
Volumes (mboe/d)(3)
2,563  2,580  (17) (1)
Distributions from equity accounted investees 47  84  (37) (44)
Change in Results
Conventional revenue(1)
Increase largely due to higher volumes on the Peace Pipeline system as higher NGL and crude market prices have resulted in increased upstream activities, combined with higher recoverable costs.
Transmission revenue(1)
Decrease largely due to a timing difference in the recognition of deferred revenue associated with the Cochin Pipeline, third party outages impacting AEGS, combined with lower volumes on the Vantage Pipeline as end users sourced their supply from the Redwater Complex and the lower U.S. dollar exchange rate.
Oil Sands revenue(1)
Decrease largely due to lower revenue from storage and rail terminals.
Operating expenses(1)
Increase largely due to a $14 million increase in power costs, of which $10 million was recovered in revenue, as a result of the higher power pool price during the third quarter of 2021.
Share of profit from equity accounted investees
Decrease largely due to lower contribution from Ruby as the owners agreed to defer distributions for
the third quarter of 2021, combined with the impact of lower U.S. dollar exchange rates.
Distributions from equity accounted investees
$46 million (2020: $53 million) from Alliance and no distributions (2020: $31 million) from Ruby. The reduction in distributions from Ruby are due to the same factors impacting share of profit from equity accounted investees discussed above.
Volumes (mboe/d)(3)
Decrease largely driven by lower contracted volumes on the Ruby Pipeline, combined with lower volumes at AEGS due to third party outages in August and September of 2021, partially offset by higher volumes on the Peace Pipeline system, discussed above, and higher volumes on the Alliance Pipeline. Volumes include 139 mboe/d (2020: 126 mboe/d) related to Alliance and 70 mboe/d (2020: 108 mboe/d) related to Ruby.
Adjusted EBITDA(2)
Decrease largely due to lower contribution from Ruby and the impact of a timing difference in the recognition of deferred revenue associated with the Cochin Pipeline, discussed above, combined with the impact of the lower U.S. dollar exchange rate and lower contribution from storage and rail terminals, partially offset by higher volumes on the Peace Pipeline system. Included in adjusted EBITDA is $62 million (2020: $66 million) related to Alliance and $24 million (2020: $47 million) related to Ruby.
Change in Adjusted EBITDA ($ millions)(2)
CHART-85B50E68C0B14126B5E.JPG
(1)    Includes inter-segment transactions. See Note 12 of the Interim Financial Statements.
(2)    Refer to the "Non-GAAP Measures" section.
(3)    Revenue volumes. See the "Abbreviations" section for definition.
(4)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy" and Note 2 to the Interim Financial Statements.
Pembina Pipeline Corporation Third Quarter 2021 9


Financial Overview for the Nine Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(4)
Change % Change
Conventional revenue(1)
1,031  951  80 
Transmission revenue(1)
315  342  (27) (8)
Oil Sands revenue(1)
327  355  (28) (8)
Total revenue(1)
1,673  1,648  25 
Operating expenses(1)
409  362  47  13 
Share of profit from equity accounted investees 95  173  (78) (45)
Depreciation and amortization included in operations 312  300  12 
Gross profit 1,047  1,159  (112) (10)
Adjusted EBITDA(2)
1,554  1,631  (77) (5)
Volumes (mboe/d)(3)
2,592  2,588  — 
Distributions from equity accounted investees 175  259  (84) (32)
Change in Results
Conventional revenue(1)
Increase largely due to higher volumes on the Peace Pipeline system as higher NGL and crude market prices have resulted in increased upstream activities, combined with higher recoverable costs.
Transmission revenue(1)
Decrease largely due to lower volumes on the Vantage Pipeline as end users sourced their supply from the Redwater Complex, combined with the impact of the lower U.S. dollar exchange rate.
Oil Sands revenue(1)
Decrease largely due to lower storage and rail terminal revenue, including fully recovered capital fees at the Edmonton South Rail Terminal in April 2020, and the sale of the Alberta Crude Terminal effective January 2021, partially offset by higher recoverable costs on the Syncrude Pipeline.
Operating expenses(1)
Increase largely due to a $33 million increase in power costs, of which $24 million was recovered in revenue, as a result of the higher power pool price during 2021, combined with increased integrity spending.
Share of profit from equity accounted investees
Decrease largely due to lower contribution from Ruby as the owners agreed to defer distributions for the second and third quarter of 2021, combined with the impact of the lower U.S. dollar exchange rate.
Distributions from equity accounted investees
$161 million (2020: $166 million) from Alliance and $13 million (2020: $93 million) from Ruby. The reduction in distributions from Ruby is due to the same factors impacting share of profit from equity accounted investees discussed above.
Volumes (mboe/d)(3)
Consistent with the prior period. Higher volumes on the Peace Pipeline system and higher seasonal volumes on the Alliance Pipeline, were largely offset by lower volumes at AEGS due to third-party outages in August and September of 2021, combined with lower contracted volumes on the Ruby Pipeline and lower volumes on the Vantage Pipeline. Volumes include 141 mboe/d (2020: 127 mboe/d) related to Alliance and 91 mboe/d (2020: 104 mboe/d) related to Ruby.
Adjusted EBITDA(2)
Decrease primarily due to lower contribution from Ruby, the impact of the lower U.S. dollar exchange rate, lower Oil Sands revenue, and lower volumes on the Vantage Pipeline. Increased operating expenses due to higher integrity spending and higher power costs not recoverable in revenue, combined with higher long-term incentives, also contributed to the decrease in adjusted EBITDA, partially offset by higher volumes on the Peace Pipeline system. Included in adjusted EBITDA is $202 million (2020: $207 million) related to Alliance and $111 million (2020: $143 million) related to Ruby.
Change in Adjusted EBITDA ($ millions)(2)
CHART-207763CDA4B84EDABC7.JPG
(1)    Includes inter-segment transactions. See Note 12 of the Interim Financial Statements.
(2)    Refer to the "Non-GAAP Measures" section.
(3)    Revenue volumes. See the "Abbreviations" section for definition.
(4)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy" and Note 2 to the Interim Financial Statements.
10 Pembina Pipeline Corporation Third Quarter 2021


Financial and Operational Overview
3 Months Ended September 30 9 Months Ended September 30
2021 2020 2021 2020
($ millions, except where noted)
Volumes(1)
Gross Profit
Adjusted EBITDA(2)
Volumes(1)
Gross Profit(3)
Adjusted EBITDA(2)
Volumes(1)
Gross Profit
Adjusted
EBITDA(2)
Volumes(1)
Gross Profit(3)
Adjusted
EBITDA(2)
Pipelines
Conventional 918  244  281  863  212  253  891  677  802  866  638  760 
Transmission 595  64  154  661  121  210  651  241  542  666  354  623 
Oil Sands 1,050  39  68  1,056  48  78  1,050  129  210  1,056  167  248 
Total 2,563  347  503  2,580  381  541  2,592  1,047  1,554  2,588  1,159  1,631 
(1)    Revenue volumes in mboe/d. See the "Abbreviations" section for definition.
(2)     Refer to the "Non-GAAP Measures" section.
(3)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy" and Note 2 to the Interim Financial Statements.
Projects & New Developments(1)
Pipelines continues to focus on the execution of various system expansions. The projects in the following table were recently placed into service.
Significant Projects In-service Date
NEBC Montney Infrastructure February 2021
Phase VI Peace Pipeline Expansion June 2020
Wapiti Condensate Lateral March 2020
The following outlines the projects and new developments within Pipelines:
Phase VII Peace Pipeline Expansion
Capital Budget: $775 million
In-service Date: First half of 2023
Status: Ahead of schedule and trending under budget
This expansion includes a new 20-inch, approximately 220 km pipeline and two new pump stations or terminal upgrades. Phase VII will add approximately 160 mbpd of incremental capacity upstream of Fox Creek, accessing capacity available on the mainlines downstream of Fox Creek. Construction is underway and progressing according to schedule.
Phase IX Peace Pipeline Expansion
Capital Budget: $120 million
In-service Date: Second half of 2022
Status: On time, trending on budget
This expansion will include new 6-inch and 16-inch pipelines debottlenecking the corridor north of Gordondale, Alberta as well as upgrades at one pump station. In addition, this expansion will see existing pipelines, which are currently batching, converted to single product lines. Phase IX also includes a pump station in the Wapiti-to-Kakwa corridor that was previously part of the Phase VII project scope.
The previously announced Phase VIII Peace Pipeline Expansion remains deferred. Initial contracts supporting the project remain intact and customers continue to signal plans which will necessitate the incremental capacity. Prior to deferral, Phase VIII had an associated capital cost of approximately $500 million but Pembina expects this level of investment to decrease given cost and scope improvements. Value engineering work is ongoing and Pembina continues to evaluate this project in discussions with its producing customers with a reactivation decision expected in the fourth quarter of 2021.
Phase VIII Peace Pipeline Expansion Status: Deferred
This expansion will include 10-inch and 16-inch pipelines in the Gordondale to La Glace corridor as well as six new pump stations or terminal upgrades located between Gordondale and Fox Creek.
(1)    For further details on Pembina's significant assets, including definitions for capitalized terms used herein that are not otherwise defined, refer to Pembina's AIF for the year ended December 31, 2020 filed at www.sedar.com (filed with the U.S. Securities and Exchange Commission at www.sec.gov under Form 40-F) and on Pembina's website at www.pembina.com.
Pembina Pipeline Corporation Third Quarter 2021 11


Facilities
Financial Overview for the Three Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(4)
Change % Change
Gas Services net revenue(1)(2)
171  145  26  18 
NGL Services net revenue(1)(2)
169  163 
Facilities net revenue(1)(2)
340  308  32  10 
Operating expenses(1)
121  99  22  22 
Share of profit from equity accounted investees
23  11  12  109 
Realized gain on commodity-related derivative financial instruments (2) —  (2) 100 
Unrealized gain on commodity-related derivative financial instruments (45) (11) (34) 309 
Depreciation and amortization included in operations
56  49  14 
Gross profit 233  182  51  28 
Adjusted EBITDA(2)
273  251  22 
Volumes (mboe/d)(3)
848  871  (23) (3)
Distributions from equity accounted investees 32  25  28 
Changes in Results
Gas Services net revenue(1)(2)
Increase largely due to Empress Infrastructure and Duvernay III being placed into service in the fourth quarter of 2020, higher volumes at Younger due to a turnaround in September 2020, and increased operating expense recoveries as a result of higher power costs, combined with the Burstall Ethane Storage Facility ("Burstall") being transferred from NGL Services to Gas Services in January 2021.
NGL Services net revenue(1)(2)
Consistent with prior period. Higher revenue from the Prince Rupert Terminal being placed into service in March 2021, combined with higher operating expense recoveries at the Redwater Complex, were largely offset by the transfer of Burstall to Gas Services and lower volumes at the Redwater Complex.
Operating expenses(1)
Increase largely due to operating expenses associated with the additional assets placed into service, discussed above, combined with higher power pool prices during the third quarter of 2021.
Share of profit from equity accounted investees
Increase mainly due to the contributions from the Veresen Midstream Hythe Developments going into service in March 2021, combined with higher volumes on Veresen Midstream's Dawson Assets.
Unrealized gain on commodity-related derivatives Certain gas processing fees are tied to AECO prices and the significant increase in the AECO price has resulted in higher unrealized gains for the third quarter of 2021.
Distributions from equity accounted investees
Consistent with the prior period. $31 million (2020: $23 million) from Veresen Midstream and $1 million (2020: $2 million) from Fort Corp.
Volumes (mboe/d)(3)
Decrease largely due to take or pay relief provided to Redwater Complex customers following third party outages during September 2021, lower volumes at the Saturn Complex due to higher deferred revenue volumes recognized in the third quarter of 2020, combined with lower supply volumes on the East NGL System, which are now being processed by the Empress Infrastructure, partially offset by higher volumes at Younger, discussed above, higher volumes on the Dawson Assets and higher volumes associated with Duvernay III being placed into service in the fourth quarter of 2020. Volumes include 89 mboe/d (2020: 76 mboe/d) related to Veresen Midstream.
Adjusted EBITDA(2)
Increase primarily due to the contribution from new assets placed into service, discussed above, combined with higher revenue at Younger. Included in adjusted EBITDA is $52 million (2020: $41 million) related to Veresen Midstream.
Change in Adjusted EBITDA ($ millions)(2)
CHART-A748D4C70749455DA02.JPG
(1)    Includes inter-segment transactions. See Note 12 of the Interim Financial Statements.
(2)    Refer to the "Non-GAAP Measures" section.
(3)    Revenue volumes. See the "Abbreviations" section for definition.
(4)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy" and Note 2 to the Interim Financial Statements.
12 Pembina Pipeline Corporation Third Quarter 2021


Financial Overview for the Nine Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(4)
Change % Change
Gas Services net revenue(1)(2)
496  424  72  17 
NGL Services net revenue(1)(2)
511  474  37 
Facilities net revenue(1)(2)
1,007  898  109  12 
Operating expenses(1)
344  281  63  22 
Share of profit from equity accounted investees
59  41  18  44 
Realized gain on commodity-related derivative financial instruments
(2) —  (2) 100 
Unrealized gain on commodity-related derivative financial instruments (62) (14) (48) 343 
Depreciation and amortization included in operations
158  149 
Gross profit 628  523  105  20 
Adjusted EBITDA(2)
812  757  55 
Volumes (mboe/d)(3)
872  874  (2) — 
Distributions from equity accounted investees 95  76  19  25 
Changes in Results
Gas Services net revenue(1)(2)
Increase largely due to Empress infrastructure and Duvernay III being placed into service in the fourth quarter of 2020, increased operating expense recoveries as a result of higher power costs, Burstall being transferred from NGL Services to Gas Services in January 2021, combined with higher volumes at Younger due to a turnaround in September 2020.
NGL Services net revenue(1)(2)
Increase primarily due to the Prince Rupert Terminal being placed into service in March 2021, combined with higher operating expense recoveries at the Redwater Complex, partially offset by the transfer of Burstall to Gas Services.
Operating expenses(1)

Increase largely due to operating expenses associated with the additional assets placed into service, discussed above, combined with higher power pool prices during the first nine months of 2021.
Share of profit from equity accounted investees
Increase mainly due to the contributions from the Veresen Midstream Hythe Developments going into service in March 2021, combined with higher volumes on Veresen Midstream's Dawson Assets.
Unrealized gain on commodity-related derivatives
Certain gas processing fees are tied to AECO prices and the significant increase in the AECO price has resulted in higher unrealized gains for the first nine months of 2021.
Distributions from equity accounted investees
$92 million (2020: $72 million) from Veresen Midstream and $3 million (2020: $4 million) from Fort Corp. The increase in distributions is due to the same reasons impacting share of profit above.
Volumes (mboe/d)(3)
Consistent with prior period. Lower supply volumes on the East NGL System, which are now being processed by the Empress Infrastructure, were largely offset by higher revenue volumes associated with Duvernay III being placed into service in the fourth quarter of 2020 and higher volumes at Younger. Volumes include 86 mboe/d (2020: 81 mboe/d) related to Veresen Midstream.
Adjusted EBITDA(2)

Increase primarily due to the contribution from Empress Infrastructure, Duvernay III and the Prince Rupert Terminal, being placed into service, discussed above, combined with higher revenue at the Redwater Complex, and the contribution from Veresen Midstream's Dawson Assets, and the Veresen Midstream Hythe Developments going into service in March of 2021, partially offset by higher operating expenses and higher long-term incentive costs driven by Pembina's increasing share price during the first nine months of 2021. Included in adjusted EBITDA is $148 million (2020: $132 million) related to Veresen Midstream.
Change in Adjusted EBITDA ($ millions)(2)
CHART-1C3B7BA8CFBF44EA830.JPG
(1)    Includes inter-segment transactions. See Note 12 of the Interim Financial Statements.
(2)    Refer to the "Non-GAAP Measures" section.
(3)    Revenue volumes. See the "Abbreviations" section for definition.
(4)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy" and Note 2 to the Interim Financial Statements.
Pembina Pipeline Corporation Third Quarter 2021 13


Financial and Operational Overview
3 Months Ended September 30 9 Months Ended September 30
2021 2020 2021 2020
($ millions, except where noted)
Volumes(1)
Gross Profit
Adjusted EBITDA(2)
Volumes(1)
Gross Profit(3)
Adjusted EBITDA(2)
Volumes(1)
Gross Profit
Adjusted
EBITDA(2)
Volumes(1)
Gross Profit(3)
Adjusted
EBITDA(2)
Facilities
Gas Services 660  150  160  657  95  138  666  363  468  664  270  420 
NGL Services 188  83  113  214  87  113  206  265  344  210  253  337 
Total 848  233  273  871  182  251  872  628  812  874  523  757 
(1)    Revenue volumes in mboe/d, with natural gas volumes converted to mboe/d from MMcf/d at a 6:1 ratio. See the "Abbreviations" section for definition.
(2)    Refer to the "Non-GAAP Measures" section.
(3)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy" and Note 2 to the Interim Financial Statements.
Projects & New Developments(1)
Facilities continues to build-out its natural gas and NGL processing and fractionation assets to service customer demand. The projects in the following table were recently placed into service.
Significant Projects In-service Date
Vancouver Wharves Expansion
June 2021
Prince Rupert Terminal March 2021
Duvernay III November 2020
Empress Infrastructure October 2020
Duvernay Sour Treatment Facilities March 2020
Veresen Midstream(2)
Hythe Developments March 2021
The following outlines the projects and new developments within Facilities:
Empress Co-generation Facility
Capital Budget: $120 million
In-service Date: Fourth quarter of 2022
Status: Ahead of schedule, on budget
The Empress Co-generation Facility will use natural gas to generate up to 45 megawatts of electrical power, thereby reducing overall operating costs by providing power and heat to the existing Empress NGL Extraction Facility. All the power will be consumed on site, thereby supplying approximately 90 percent of the site's power requirements. Further, this project will contribute to annual greenhouse gas emission reductions at the Empress NGL Extraction Facility through the utilization of the co-generation waste heat and the low-emission power generated. Pembina anticipates a reduction of approximately 90,000 tonnes of carbon dioxide equivalent per year based on the current energy demand of the Empress NGL Extraction Facility. Construction is progressing and the mechanical contractor is expected to mobilize to site in November 2021.
The Prince Rupert Terminal Expansion remains deferred. Engineering of the expansion is well advanced and Pembina expects to make a final investment decision in the first quarter of 2022.
Prince Rupert Terminal Expansion Status: Deferred
The Prince Rupert Terminal Expansion will increase the export capacity of the Prince Rupert Terminal.
(1)    For further details on Pembina's significant assets, including definitions for capitalized terms used herein that are not otherwise defined, refer to Pembina's AIF for the year ended December 31, 2020 filed at www.sedar.com (filed with the U.S. Securities and Exchange Commission at www.sec.gov under Form 40-F) and on Pembina's website at www.pembina.com.
(2)    Veresen Midstream is an equity accounted investee, in which Pembina had a 45 percent interest in as of September 30, 2021. Results from Veresen Midstream impact share of profit from equity accounted investees and proportionally consolidated metrics. See Note 5 to the Interim Financial Statements.
14 Pembina Pipeline Corporation Third Quarter 2021


Marketing & New Ventures
Financial Overview for the Three Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(2)
Change % Change
Marketing revenue(1)
1,393  752  641  85 
Cost of goods sold(1)
1,268  720  548  76 
Net revenue(1)(3)
125  32  93  291 
Share of profit (loss) from equity accounted investees 31  (5) 36  (720)
Realized loss (gain) on commodity-related derivative financial instruments 45  (7) 52  (743)
Unrealized (gain) loss on commodity-related derivative financial instruments (2) 17  (19) (112)
Depreciation and amortization included in operations 13  12 
Gross profit 100  95  1,900 
Adjusted EBITDA(3)
109  34  75  221 
Volumes (mboe/d)(4)
177  169 
Distributions from equity accounted investees 27  25  1,250 
Change in Results
Net revenue(1)(3)
Increase due to higher NGL and crude oil market prices, resulting in higher margins, combined with higher marketed NGL volumes, discussed below, partially offset by an increase in cost of goods sold related to Prince Rupert Terminal and Empress Infrastructure being placed into service, and rail transportation costs to re-position propane to Corunna for sale in the fourth quarter of 2021 and first quarter of 2022.
Share of profit (loss) from equity accounted investees Increase largely due to higher revenues at Aux Sable as a result of higher NGL margins and a wider
AECO-Chicago natural gas price differential.
Realized loss (gain) on commodity-related derivatives
Realized loss due to higher NGL market prices during the third quarter of 2021, which also drove higher margins on NGL sales, resulting in a realized loss on NGL-based derivative instruments for the period, compared to realized gains on NGL-based derivative instruments recognized during the third quarter of 2020. Pembina utilizes derivative instruments to stabilize the results of its marketing business.
Unrealized (gain) loss on commodity-related derivatives Unrealized gain on commodity-related derivatives primarily due to contracts maturing in the period, partially offset by the increase in the forward prices for NGL and crude oil during the third quarter of 2021 and newly added contracts.
Distributions from equity accounted investees
$27 million (2020: $2 million) from Aux Sable. Increase largely due to the higher margins at Aux Sable, discussed above.
Volumes (mboe/d)(4)
Marketed NGL volumes increased as sales returned to pre-pandemic levels compared to the third quarter of 2020 when Pembina built up storage positions due to lower commodity prices. Revenue volumes includes 35 mboe/d (2020: 37 mboe/d) related to Aux Sable.
Adjusted EBITDA(3)
Increase largely due to higher margins on NGL and crude oil sales as a result of the higher NGL and crude oil prices during the third quarter of 2021 and higher marketed NGL volumes, combined with a higher contribution from Aux Sable, discussed above, partially offset by the realized loss on commodity-related derivatives. Included in adjusted EBITDA is $36 million (2020: $1 million) related to Aux Sable.
Change in Adjusted EBITDA ($ millions)(3)
CHART-7E12D0A2473946728B1.JPG
(1)    Includes inter-segment transactions. See Note 12 of the Interim Financial Statements.
(2)    Comparative 2020 period has been restated. See "Restatement of Revenue and Cost of Goods Sold" and Note 2 to the Interim Financial Statements.
(3)    Refer to the "Non-GAAP Measures" section.
(4)    Marketed NGL volumes. See the "Abbreviations" section for definition.
Pembina Pipeline Corporation Third Quarter 2021 15


Financial Overview for the Nine Months Ended September 30
Results of Operations
($ millions, except where noted) 2021
2020(2)
Change % Change
Marketing revenue(1)
3,827  2,074  1,753  85 
Cost of goods sold(1)
3,463  2,006  1,457  73 
Net revenue(1)(3)
364  68  296  435 
Share of profit (loss) from equity accounted investees 44  (2) 46  (2,300)
Realized loss (gain) on commodity-related derivative financial instruments 166  (60) 226  (377)
Unrealized loss on commodity-related derivative financial instruments 19  12  58 
Depreciation and amortization included in operations 38  37 
Adjusted gross profit 185  77  108  140 
Adjusted EBITDA(3)
237  118  119  101 
Volumes (mboe/d)(4)
190  173  17  10 
Distributions from equity accounted investees 63  15  48  320 
Change in Results
Net revenue(1)(3)
Increase largely due to higher crude oil and NGL market prices, resulting in higher margins, combined with higher marketed NGL volumes, discussed below, partially offset by an increase in cost of goods sold related to Prince Rupert Terminal and Empress Infrastructure being placed into service, and rail transportation costs to re-position propane to Corunna for sale in the fourth quarter of 2021 and first quarter of 2022.
Share of profit (loss) from equity accounted investees Increase largely due to higher revenues at Aux Sable as a result of higher NGL margins and a wider
AECO-Chicago natural gas price differential.
Realized loss (gain) on commodity-related derivatives Realized loss due to higher NGL and crude oil market prices during the period, which also drove higher margins on NGL and crude sales, resulting in a realized loss on NGL- and crude oil-based derivative instruments for the period, compared to realized gains recognized in the first nine months of 2021. Pembina utilizes derivative instruments to stabilize the results of its marketing business.
Unrealized loss on commodity-related derivatives
Consistent with prior period.
Distributions from equity accounted investees
$63 million (2020: $15 million) from Aux Sable. Increase largely due to the higher margins at Aux Sable, discussed above.
Volumes (mboe/d)(4)
Marketed NGL volumes increased as Pembina monetized storage positions during the first quarter of 2021, that were built up during the second and third quarters of 2020, when commodity prices were lower, while increased NGL supply volumes contributed to higher sales volumes in the second and third quarter of 2021 compared to the same periods in 2020. Revenue volumes includes 36 mboe/d (2020: 37 mboe/d) related to Aux Sable.
Adjusted EBITDA(3)
Increase largely due to higher margins on NGL and crude oil sales as a result of the higher NGL and crude oil prices during the first nine months of 2021 and higher marketed NGL volumes, combined with a higher contribution from Aux Sable, discussed above, partially offset by the realized loss on commodity-related derivatives due to higher NGL market prices. Included in adjusted EBITDA is $62 million (2020: $14 million) related to Aux Sable.
Change in Adjusted EBITDA ($ millions)(3)
CHART-20B74AF848BE46B580F.JPG
(1)    Includes inter-segment transactions. See Note 12 of the Interim Financial Statements.
(2)    Comparative 2020 period has been restated. See "Restatement of Revenue and Cost of Goods Sold" and Note 2 to the Interim Financial Statements.
(3)    Refer to the "Non-GAAP Measures" section.
(4)    Marketed NGL volumes. See the "Abbreviations" section for definition.
16 Pembina Pipeline Corporation Third Quarter 2021


Financial and Operational Overview
3 Months Ended September 30 9 Months Ended September 30
2021 2020 2021 2020
($ millions, except where noted)
Volumes(1)
Gross Profit
Adjusted EBITDA(2)
Volumes(1)
Gross Profit
Adjusted EBITDA(2)
Volumes(1)
Gross Profit
Adjusted
EBITDA(2)
Volumes(1)
Gross Profit
Adjusted
EBITDA(2)
Marketing & New Ventures
Marketing 177  100  111  169  36  190  185  246  173  74  127 
New Ventures(3)
    (2) —  (2)     (9) —  (9)
Total 177  100  109  169  34  190  185  237  173  77  118 
(1)    Marketed NGL volumes in mboe/d. See the "Abbreviations" section for definition.
(2)    Refer to the "Non-GAAP Measures" section.
(3)    All New Ventures projects have not yet commenced operations and therefore have no volumes.
Projects & New Developments(1)
Pembina's New Ventures group continues to advance business opportunities in petrochemicals, liquefied natural gas ("LNG") and low-carbon energy. New Ventures is focused on developing opportunities that integrate into Pembina's core businesses, while progressing projects that will extend Pembina's value-chain and benefit stakeholders. Pembina has formed a strategic partnership agreement with the Haisla First Nation to develop the proposed Cedar LNG Project, a floating LNG facility strategically positioned to leverage Canada's abundant natural gas supply and British Columbia's growing LNG infrastructure to produce industry-leading low‑carbon, low-cost Canadian LNG for overseas markets. The Cedar LNG Project is expected to be the largest First Nation-owned infrastructure project in Canada and have one of the cleanest environmental profiles in the world. In addition, Pembina and TC Energy Corporation intend to jointly develop the Alberta Carbon Grid, a world-scale carbon transportation and sequestration system, which will enable Alberta-based industries to effectively manage their greenhouse gas emissions, contribute positively to Alberta's lower-carbon economy and create sustainable long-term value for Pembina and TC Energy stakeholders.
(1)    For further details on Pembina's significant assets, including definitions for capitalized terms used herein that are not otherwise defined, refer to Pembina's AIF for the year ended December 31, 2020 filed at www.sedar.com (filed with the U.S. Securities and Exchange Commission at www.sec.gov under Form 40-F) and on Pembina's website at www.pembina.com.
Pembina Pipeline Corporation Third Quarter 2021 17


4. LIQUIDITY & CAPITAL RESOURCES
Available Sources of Liquidity
($ millions) September 30, 2021 December 31, 2020
Working capital(1)
(1,077) (792)
Variable rate debt(2)(3)
Bank debt 1,443  1,534 
Variable rate debt swapped to fixed (319) (318)
Total variable rate loans and borrowings outstanding (weighted average interest rate of 1.3% (2020: 1.6%)) 1,124  1,216 
Fixed rate debt(2)
Senior unsecured medium-term notes 9,050  9,300 
Variable rate debt swapped to fixed 319  318 
Total fixed rate loans and borrowings outstanding (weighted average interest rate of 3.9% (2020: 3.9%)) 9,369  9,618 
Total loans and borrowings outstanding 10,493  10,834 
Cash and unutilized debt facilities 2,008  2,685 
Subordinated hybrid notes (weighted average interest rate of 4.8% (2020: nil)) 600  — 
(1)    As at September 30, 2021, working capital included $900 million (December 31, 2020: $600 million) associated with the current portion of long-term debt.
(2)    Face value.
(3)    Includes U.S. $250 million variable rate debt outstanding at September 30, 2021 (December 31, 2020: U.S. $250 million).
Pembina currently anticipates that its cash flow from operating activities, the majority of which is derived from fee-based contracts, will be more than sufficient to meet its operating obligations, to fund its dividend and to fund its capital investments in the short-term and long-term. Pembina expects to source funds required for debt maturities from cash, its credit facilities and by accessing the capital markets, as required. Based on its successful access to financing in the capital markets over the past several years, Pembina expects to continue to have access to additional funds as required. Refer to "Risk Factors – General Risk Factors – Additional Financing and Capital Resources" in Pembina's MD&A for the year ended December 31, 2020 and Note 27 to the Consolidated Financial Statements for more information. Management continues to monitor Pembina's liquidity situation and remains satisfied that the leverage employed in Pembina's capital structure is sufficient and appropriate given the characteristics and operations of the underlying asset base.
Management may adjust Pembina's capital structure as a result of changes in economic conditions or the risk characteristics of the underlying assets. To maintain or modify Pembina's capital structure in the future, Pembina may renegotiate debt terms, repay existing debt, seek new borrowings, issue additional equity or hybrid securities and/or repurchase common or preferred shares.
As at September 30, 2021, Pembina's credit facilities consisted of: an unsecured $2.5 billion (December 31, 2020: $2.5 billion) revolving credit facility, which includes a $750 million (December 31, 2020: $750 million) accordion feature and matures in June 2026; an unsecured $500 million (December 31, 2020: $500 million) non-revolving term loan, which matures in August 2022; an unsecured U.S. $250 million (December 31, 2020: U.S. $250 million) non-revolving term loan, which matures in May 2025; and an operating facility of $20 million (December 31, 2020: $20 million), which matures in May 2022 and is typically renewed on an annual basis (collectively, the "Credit Facilities"). There are no mandatory principal repayments due over the term of the Credit Facilities, with principal repayment not due until maturity. On March 25, 2021, Pembina cancelled its $800 million revolving credit facility, which was entered into in April 2020 to provide additional liquidity and flexibility in Pembina’s capital structure given market conditions at the time. No balance was outstanding on the cancellation date. Pembina is required to meet certain specific and customary affirmative and negative financial covenants under the indenture governing its medium-term notes and the agreements governing its Credit Facilities, including a requirement to maintain certain financial ratios. See "Liquidity & Capital Resources – Covenants" below for more information. Pembina is also subject to customary restrictions on its operations and activities under the indenture governing its medium-term notes and the agreements governing its Credit Facilities, including restrictions on the granting of security, incurring indebtedness and the sale of its assets.
18 Pembina Pipeline Corporation Third Quarter 2021


Financing Activity
On January 25, 2021, Pembina closed a $600 million offering of Fixed-to-Fixed Rate Subordinated Hybrid Notes (the "Series 1 Subordinated Notes"). The Series 1 Subordinated Notes have a fixed 4.80 percent interest rate, payable semi-annually, which resets on January 25, 2031, and on every fifth anniversary thereafter, based on the five-year Government of Canada yield plus: (i) 4.17 percent for the period from, and including, January 25, 2031 to, but excluding January 25, 2051; and (ii) 4.92 percent for the period from, and including, January 25, 2051 to, but excluding January 25, 2081. Pembina used the net proceeds of the offering of the Series 1 Subordinated Notes to fund the redemption of its outstanding Cumulative Redeemable Minimum Rate Reset Class A Preferred Shares, Series 11, its outstanding Cumulative Redeemable Minimum Rate Reset Class A Preferred Shares, Series 13, to repay outstanding debt, as well as for general corporate purposes.
On April 30, 2021, Pembina completed an extension on its $2.5 billion revolving credit facility, which now matures on June 1, 2026.
Covenants
Pembina's financial covenants under the indenture governing its medium-term notes and the agreements governing the Credit Facilities include the following:
Debt Instrument
Financial Covenant(1)
Ratio
Ratio as at September 30, 2021
Senior unsecured medium-term notes Funded Debt to Capitalization Maximum 0.70 0.41 
Credit Facilities
Debt to Capital
Maximum 0.70
0.42 
(1)    Terms as defined in relevant agreements.
Pembina was in compliance with all covenants under the note indenture governing its medium-term notes and the agreements governing its Credit Facilities as at September 30, 2021 (December 31, 2020: in compliance).
Credit Risk
Pembina continues to actively monitor and reassess the creditworthiness of its counterparties. While the global economic slowdown has eased, the outlook for the global economic recovery remains uncertain and the potential for volatility in demand for crude oil and other commodities as a result of the ongoing COVID-19 pandemic could increase Pembina's counterparty risk, as uncertainty and the potential for volatility in the demand for crude oil could negatively impact the financial position of Pembina's customers and related parties and their access to credit, capital markets and other sources of liquidity. The majority of Pembina's credit exposure is to investment grade or split-investment grade counterparties. Pembina assesses all counterparties during the on-boarding process and actively monitors credit limits and exposure across the business. Financial assurances to mitigate and reduce risk may include guarantees, letters of credit and cash. Letters of credit totaling $96 million (December 31, 2020: $130 million) were held as at September 30, 2021, primarily in respect of customer trade receivables.
Pembina Pipeline Corporation Third Quarter 2021 19


Credit Ratings
The following information with respect to Pembina's credit ratings is provided as such information relates to Pembina's financing costs and liquidity. Specifically, credit ratings affect Pembina's ability to obtain short-term and long-term financing and the cost of such financing. A reduction in the current ratings of Pembina's debt by its rating agencies, particularly a downgrade below investment-grade ratings, could adversely affect Pembina's cost of financing and its access to sources of liquidity and capital. In addition, changes in credit ratings and the associated costs may affect Pembina's ability to enter into normal course derivative or hedging transactions. Credit ratings are intended to provide investors with an independent measure of the credit quality of any issues of securities. The credit ratings assigned by the rating agencies are not recommendations to purchase, hold or sell the securities, nor do the credit ratings comment on the market price or suitability for a particular investor. Any credit rating may not remain in effect for a given period of time or may be revised or withdrawn entirely by a rating agency in the future if, in its judgment, circumstances so warrant.
On April 28, 2021, DBRS Limited ("DBRS") upgraded its ratings for Pembina's senior unsecured medium-term notes to 'BBB (high)', to 'BBB (low)' for the Series 1 Subordinated Notes and to 'Pfd-3 (high)' for each issued series of Pembina's Class A Preferred Shares, other than the Class A Preferred Shares, Series 2021-A (the "Series 2021-A Class A Preferred Shares"), which are deliverable to the holders of the Series 1 Subordinated Notes following the occurrence of certain bankruptcy or insolvency events in respect of Pembina.
The long-term corporate credit rating assigned by S&P Global Ratings ("S&P") on Pembina is 'BBB'. S&P has also assigned a debt rating of 'BBB' to Pembina's senior unsecured medium-term notes, a debt rating of 'BB+' to the Series 1 Subordinated Notes, and a rating of 'P-3 (High)' to each issued series of Pembina's Class A Preferred Shares, other than the Series 2021-A Class A Preferred Shares. S&P affirmed Pembina's credit rating during the second quarter of 2021.
Refer to "Description of the Capital Structure of Pembina – Credit Ratings" in the AIF for further information.
20 Pembina Pipeline Corporation Third Quarter 2021


Contractual Obligations and Off-Balance Sheet Arrangements
Contractual Obligations
Pembina had the following contractual obligations outstanding at September 30, 2021:
Contractual Obligations(1)
Payments Due By Period
($ millions) Total Less than 1 year 1 – 3 years 3 – 5 years After 5 years
Leases(2)
1,010  118  186  155  551 
Long-term debt(3)
16,523  1,366  2,382  2,609  10,166 
Construction commitments(4)
892  335  48  29  480 
Other
543  91  127  68  257 
Total contractual obligations
18,968  1,910  2,743  2,861  11,454 
(1)
Pembina enters into product purchase agreements and power purchase agreements to secure supply for future operations. Purchase prices of both NGL and power are dependent on current market prices. Volumes and prices for NGL and power contracts cannot be reasonably determined, and therefore, an amount has not been included in the contractual obligations schedule. Product purchase agreements range from one to 8 years and involve the purchase of NGL products from producers. Assuming product is available, Pembina has secured between 12 and 138 mbpd of NGL each year up to and including 2029. Power purchase agreements range from one to 24 years and involve the purchase of power from electrical service providers. Pembina has secured up to 81 megawatts per day each year up to and including 2045.
(2)
Includes terminals, rail, office space, land and vehicle leases.
(3)
Includes loans and borrowings, subordinated hybrid notes and interest payments on Pembina's senior unsecured medium-term notes and subordinated hybrid notes. Excludes deferred financing costs.
(4)
Excluding significant projects that are awaiting regulatory approval, projects which Pembina is not committed to construct, and projects that are executed by equity accounted investees.
Off-Balance Sheet Arrangements
As at September 30, 2021, Pembina does not have any off-balance sheet arrangements that have, or are reasonably likely to have, a current or future effect on Pembina's financial condition, results of operations, liquidity or capital investments.
Letters of Credit
Pembina has provided letters of credit to various third parties in the normal course of conducting business. The letters of credit include financial guarantees to counterparties for product purchases and sales, transportation services, utilities, engineering and construction services. The letters of credit have not had and are not expected to have a material impact on Pembina's financial position, earnings, liquidity or capital resources. As at September 30, 2021, Pembina had $166 million (December 31, 2020: $91 million) in letters of credit issued.
Pembina Pipeline Corporation Third Quarter 2021 21


5. SHARE CAPITAL
Common Shares
On February 25, 2021, the Toronto Stock Exchange ("TSX") accepted the Company's notice of intention to commence a normal course issuer bid ("NCIB") that allows the Company to repurchase, at its discretion, up to approximately 27.5 million common shares through the facilities of the TSX, the New York Stock Exchange and/or alternative Canadian trading systems or as otherwise permitted by applicable securities law, subject to certain restrictions on the number of common shares that may be purchased on a single day. Common shares purchased by the Company will be cancelled. The program commenced March 2, 2021 and will terminate on March 1, 2022 or on such earlier date as the Company completes its purchases pursuant to the notice of intention. No common shares were purchased by Pembina during the first nine months of 2021.
Common Share Dividends
Common share dividends are payable if, as and when declared by Pembina's Board of Directors. The amount and frequency of dividends declared and payable is at the discretion of Pembina's Board of Directors, which considers earnings, cash flow, capital requirements, the financial condition of Pembina and other relevant factors when making its dividend determination.
Preferred Shares
On January 25, 2021 in connection with the offering of the Series 1 Subordinated Notes, Pembina issued 600,000 Series 2021-A Class A Preferred Shares, to Computershare Trust Company of Canada, to be held in trust as treasury shares to satisfy Pembina's obligations under the indenture governing the Series 1 Subordinated Notes.
On March 1, 2021, Pembina redeemed all of the 6.8 million issued and outstanding Cumulative Redeemable Minimum Rate Reset Class A Preferred Shares, Series 11 (the "Series 11 Class A Preferred Shares") for a redemption price equal to $25.00 per Series 11 Class A Preferred Share, less taxes required to be deducted or withheld by the Company.
On June 1, 2021, Pembina redeemed all of the 10 million issued and outstanding Cumulative Redeemable Minimum Rate Reset Class A Preferred Shares, Series 13 (the "Series 13 Class A Preferred Shares") for a redemption price equal to $25.00 per Series 13 Class A Preferred Shares, less taxes required to be deducted or withheld by the Company.
Preferred Share Dividends
Other than in respect of the Series 2021-A Class A Preferred Shares, the holders of Pembina's Class A Preferred Shares are entitled to receive fixed cumulative dividends. Dividends on the Series 1, 3, 5, 7, 9 and 21 Class A Preferred Shares are payable quarterly on the first day of March, June, September and December, if, as and when declared by the Board of Directors of Pembina. Dividends on the Series 15, 17 and 19 Class A Preferred Shares are payable on the last day of March, June, September and December in each year, if, as and when declared by the Board of Directors of Pembina. Dividends on the Series 23 and 25 Class A Preferred Shares are payable on the 15th day of February, May, August and November in each year, if, as and when declared by the Board of Directors of Pembina.
Dividends are not payable on the Series 2021-A Class A Preferred Shares, nor shall any dividends accumulate or accrue, prior to delivery to the holders of the Series 1 Subordinated Notes following the occurrence of certain bankruptcy or insolvency events in respect of Pembina. Thereafter, dividends on the Series 2021-A Class A Preferred Shares are payable on the 25th day of January and July in each year, if, as and when declared by the Board of Directors.
22 Pembina Pipeline Corporation Third Quarter 2021


Outstanding Share Data
Issued and outstanding (thousands)(1)
October 29, 2021
Common shares 550,255 
Stock options 21,345 
Stock options exercisable 12,049 
Series 1 Class A Preferred shares 10,000 
Series 3 Class A Preferred Shares 6,000 
Series 5 Class A Preferred Shares 10,000 
Series 7 Class A Preferred Shares 10,000 
Series 9 Class A Preferred Shares 9,000 
Series 15 Class A Preferred Shares 8,000 
Series 17 Class A Preferred Shares 6,000 
Series 19 Class A Preferred Shares 8,000 
Series 21 Class A Preferred Shares 16,000 
Series 23 Class A Preferred Shares 12,000 
Series 25 Class A Preferred Shares 10,000 
(1)    Pembina issued 600,000 Series 2021-A Class A Preferred shares to the Computershare Trust Company of Canada, to be held in trust to satisfy its obligations under the indenture governing the Series 1 Subordinated Notes, in connection with the issuance of the Series 1 Subordinated Notes.
6. CAPITAL INVESTMENTS
Capital Invested
3 Months Ended September 30 9 Months Ended September 30
($ millions) 2021 2020 2021 2020
Pipelines 174  53  352  511 
Facilities 26  98  102  296 
Marketing & New Ventures 3  10  15  34 
Corporate and other projects 6  13  13  27 
Total capital invested(1)(2)
209  174  482  868 
(1)    Includes $19 million for the three months ended September 30, 2021 (2020: $29 million) related to non-recoverable sustainment activities.
(2)    Includes $49 million for the nine months ended September 30, 2021 (2020: $76 million) related to non-recoverable sustainment activities.
In both 2021 and 2020, Pipeline capital investments continued to be primarily related to Pembina's Peace Pipeline system expansion projects with increased spending on the NEBC Town Terminal Project in 2021. In 2021, Facilities capital investments were largely related to continued expansion at Empress, the Prince Rupert Terminal and Vancouver Wharves. In 2020, Facilities capital investments included construction on Duvernay III, Empress Expansion and the Prince Rupert Terminal. Marketing & New Ventures had capital investments primarily related to offshore LNG projects in 2021 and the Jordan Cove LNG project in 2020.
Contributions to Equity Accounted Investees
3 Months Ended September 30 9 Months Ended September 30
($ millions) 2021 2020 2021 2020
Aux Sable   —  1 
Veresen Midstream 18  28  29  69 
CKPC   —    152 
Total 18  28  30  224 
Contributions made to Veresen Midstream during both 2021 and 2020 were largely related to the construction of the Hythe Developments.
There were no contributions made to CKPC during 2021, following the indefinite suspension of the propane dehydration ("PDH") plant and polypropylene upgrading facility ("PDH/PP Facility") announced in the fourth quarter of 2020.

Pembina Pipeline Corporation Third Quarter 2021 23


7. SELECTED QUARTERLY INFORMATION
Selected Quarterly Operating Information
(mboe/d) 2021 2020 2019
Q3 Q2 Q1 Q4 Q3 Q2 Q1 Q4
Volumes(1)(2)
Pipelines
Conventional Pipelines
918  892  862  993  863  834  902  958 
Transmission Pipelines 595  685  674  684  661  668  668  646 
Oil Sands Pipelines 1,050  1,050  1,051  1,053  1,056  1,053  1,059  1,063 
Facilities
Gas Services
660  662  677  673  657  658  678  690 
NGL Services 188  211  218  211  214  214  201  220 
Total 3,411  3,500  3,482  3,614  3,451  3,427  3,508  3,577 
(1)    Revenue volumes. See the "Abbreviations" section for definition.
(2)    Includes Pembina's proportionate share of volumes from equity accounted investees.
Deferred Take-or-pay Revenue
($ millions) 2021 2020 2019
Q3 Q2 Q1 Q4 Q3 Q2 Q1 Q4
Pipelines
Opening balance
32  22  42  45  22  17 
Revenue deferred
48  45  42  52  66  53  40  31 
Revenue recognized
(59) (35) (23) (91) (69) (30) (26) (40)
Ending take-or-pay contract liability balance
21  32  22  42  45  22 
Facilities
Opening balance
3  —  —  —  — 
Revenue deferred
  —  — 
Revenue recognized
(3) —  —  —  (3) —  —  — 
Ending take-or-pay contract liability balance
  —  —  — 
Quarterly Segmented Adjusted EBITDA ($ millions)(1)
CHART-C247DA0EADEF4605A3B.JPG
(1)    Refer to the "Non-GAAP Measures" section.
24 Pembina Pipeline Corporation Third Quarter 2021


Quarterly Financial Information
($ millions, except where noted)
2021(2)
2020(2)
2019(2)
Q3 Q2 Q1 Q4 Q3 Q2 Q1 Q4
Revenue 2,149  1,902  2,016  1,680  1,496  1,229  1,548  1,668 
Net revenue(1)
961  894  999  954  849  776  865  837 
Operating expenses 187  186  182  201  178  154  179  177 
Realized loss (gain) on commodity-related derivative financial instruments 43  33  88  (7) (36) (17) (8)
Share of profit (loss) from equity accounted investees 75  52  71  (244) 62  66  84  89 
Gross profit 682  550  630  247  568  460  733  605 
Earnings (loss) 588  254  320  (1,216) 323  258  319  150 
Earnings (loss) per common share – basic and diluted (dollars)
1.01  0.39  0.51  (2.28) 0.52  0.40  0.51  0.22 
Cash flow from operating activities 913  584  456  766  434  642  410  728 
Cash flow from operating activities per common share – basic (dollars)(1)
1.66  1.06  0.83  1.39  0.78  1.17  0.75  1.41 
Adjusted cash flow from operating activities(1)
786  538  582  603  524  586  576  576 
Adjusted cash flow from operating activities per common share – basic (dollars)(1)
1.43  0.98  1.06  1.10  0.95  1.07  1.05  1.11 
Common shares outstanding (millions):
Weighted average – basic 550  550  550  550  550  550  549  518 
Weighted average – diluted 551  551  550  550  550  550  549  519 
End of period 550  550  550  550  550  550  550  548 
Common share dividends declared 347  347  346  346  346  347  346  314 
Dividends per common share
0.63  0.63  0.63  0.63  0.63  0.63  0.63  0.60 
Preferred share dividends declared 31  35  36  38  38  37  38  34 
Capital investments 209  146  127  161  174  211  483  429 
Contributions to equity accounted investees 18  —  12  —  28  194  120 
Distributions from equity accounted investees 106  112  115  109  111  116  123  123 
Adjusted EBITDA(1)
850  778  835  866  796  789  830  787 
(1)    Refer to the "Non-GAAP Measures" section.
(2)    Comparative 2020 period has been restated. See "Voluntary Change in Accounting Policy", "Restatement of Revenue and Cost of Goods Sold" and Note 2 to the Interim Financial Statements. The restatement reduces revenue and cost of goods sold for all quarterly comparative periods, including Q2 2021: $52 million, Q1 2021: $29 million, Q4 2020: $14 million, Q3 2020: $73 million, Q2 2020: $39 million, Q1 2020: $123 million, and Q4 2019: $86 million.
During the periods in the table above, Pembina's financial and operating results were impacted by the following factors and trends:
Impairments recognized on Pembina's interests in Ruby, CKPC and the assets associated with Jordan Cove in the fourth quarter of 2020 and the partial impairment of Pembina's interest in Ruby in the fourth quarter of 2019;
The Kinder Acquisition, which was completed on December 16, 2019;
The COVID-19 pandemic and the resulting decrease in demand for commodities starting in the second quarter of 2020, which led to a significant decline in global energy prices and a reduction in capital spending budgets by Pembina and its customers in 2020, and the subsequent recovery in demand for commodities and global energy prices in 2021;
Volatility in the AECO-Chicago natural gas price differential, power pool prices and foreign exchange rates impacting operating results;
New large-scale growth projects across Pembina's business being placed into service;
Volatility in commodity market prices impacting margins within the marketing business, partially mitigated through Pembina's risk management program;
Higher net finance costs impacting earnings associated with debt related to financing acquisitions, growth projects, volatility in foreign exchange rates and volatility in Pembina's share price impacting incentive costs;
Increased common and preferred shares outstanding and corresponding dividends due to the Kinder Acquisition;
Contract expiries on certain assets; and
The receipt of the Arrangement Termination Payment.
Pembina Pipeline Corporation Third Quarter 2021 25


8. SELECTED EQUITY ACCOUNTED INVESTEE INFORMATION
Loans and Borrowings of Equity Accounted Investees
Under equity accounting, the assets and liabilities of an investment are net into a single line item in the Consolidated Statement of Financial Position, "Investments in Equity Accounted Investees". To assist readers' understanding and to evaluate the capitalization of Pembina's investments, loans and borrowings associated with investments in equity accounted investees are presented below based on Pembina's proportionate ownership in such investments, as at September 30, 2021. In addition, certain of the equity accounted investees have borrowing arrangements with an amortization structure, thereby necessitating periodic repayments of principal. These repayments occur prior to the distribution of residual cash flow to Pembina. The loans and borrowings and amortization schedules are presented below and classified by the division in which the results for the investment are reported. Please refer to the "Abbreviations" section for a summary of Pembina's investments in equity accounted investees and the division in which their results are reported.
($ millions)(1)
September 30, 2021 December 31, 2020
Pipelines 877  926 
Facilities 1,198  1,200 
Total 2,075  2,126 
(1)    Balances reflect Pembina's ownership percentage of the outstanding balance face value.
Amortization Schedule of Loans and Borrowings of Equity Accounted Investees
9 Months Ended Remainder of
($ millions)(1)
September 30, 2021 2021 2022  2023  2024  2025+
Pipelines 87  33  623  62  67  92 
Facilities 2  12  36  36  1,114  — 
Total 89  45  659  98  1,181  92 
(1)    Balances reflect Pembina's ownership percentage of the outstanding balance face value.
Financing Activities for Equity Accounted Investees
On April 19, 2021, Ruby fully repaid the $16 million outstanding on its term loan.
Commitments to Equity Accounted Investees
Pembina has commitments to provide contributions to certain equity accounted investees based on annual budgets approved by the joint venture partners and contractual agreements.
Credit Risk for Equity Accounted Investees
At September 30, 2021, Pembina's various equity accounted investees held letters of credit totaling $73 million (December 31, 2020: $105 million) primarily in respect of customer trade receivables.
Cedar LNG Acquisition
On June 4, 2021, Pembina acquired a 49.9 percent interest in a joint venture with the Haisla Nation to develop the Cedar LNG Project, a LNG facility located on the coast of British Columbia within the Douglas Channel on Haisla-owned land. Pembina's investment of $129 million at September 30, 2021 included $76 million of accrued contingent consideration payable on achievement of certain conditions. Under the terms of the agreement, Pembina has commitments to make additional payments on a positive final investment decision as well as contributions to fund development costs and annual operating budgets.
26 Pembina Pipeline Corporation Third Quarter 2021


9. OTHER
Related Party Transactions
Pembina enters into transactions with related parties in the normal course of business and on terms equivalent to those that prevail in arm's length transactions, unless otherwise noted. Pembina contracts capacity from Alliance and Veresen Midstream, its equity accounted investees, and advances funds to support operations and provides services, on a cost recovery basis, to equity accounted investees.  
On January 6, 2021, Pembina advanced U.S. $8 million to Ruby Pipeline L.L.C., which was subsequently impaired.
For the three and nine months ended September 30, 2021, Pembina had no other transactions with "related parties" (as defined in IAS 24 Related Party Disclosures) except those pertaining to contributions to Pembina's defined benefit pension plan and remuneration of key management personnel and the Board of Directors of Pembina, in the ordinary course of their employment or directorship agreements, respectively.
Risk Management
Pembina's risk management strategies, policies and limits, ensure risks and exposures are aligned to its business strategy and risk tolerance. Pembina's Board of Directors is responsible for providing risk management oversight at Pembina and oversees how management monitors compliance with Pembina's risk management policies and procedures and reviews the adequacy of this risk framework in relation to the risks faced by Pembina.
Pembina's financial risks are consistent with those discussed in Note 27 of the Consolidated Financial Statements. Pembina has exposure to counterparty credit risk, liquidity risk and market risk. As at September 30, 2021, the Company has entered into certain financial derivative contracts in order to manage commodity price, foreign exchange and interest rate risk. These instruments are not used for trading or speculative purposes. For more information on Pembina's derivative instruments, refer to Note 14 to the Interim Financial Statements.
Pembina Pipeline Corporation Third Quarter 2021 27


Disclosure Controls and Procedures and Internal Control over Financial Reporting
Disclosure Controls and Procedures
Pembina maintains disclosure controls and procedures ("DC&P") designed to provide reasonable assurance that information required to be disclosed in Pembina's annual filings, interim filings and other reports filed or submitted by it under securities laws is recorded, processed, summarized and reported accurately and in the time periods specified under such securities laws, and include controls and procedures designed to ensure such information is accumulated and communicated to Pembina's management, including its certifying officers, as appropriate to allow timely decisions regarding required disclosure. As at September 30, 2021, the President and Chief Executive Officer ("CEO") and the Senior Vice President and Chief Financial Officer ("CFO") have concluded that Pembina's DC&P were not effective as at that date as a result of the material weakness described below.
Management's Report on Internal Control Over Financial Reporting
Pembina maintains internal control over financial reporting ("ICFR") which is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with IFRS, and include policies and procedures that: (a) pertain to the maintenance of records that in reasonable detail accurately and fairly reflect the transactions and dispositions of the assets of Pembina; (b) are designed to provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with IFRS, and that receipts and expenditures of Pembina are being made only in accordance with authorizations of management and directors of Pembina; and (c) are designed to provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of Pembina's assets that could have a material effect on Pembina's financial statements. Management is responsible for establishing and maintaining DC&P and ICFR, as defined in National Instrument 52-109 Certification of Disclosure in Issuers' Annual and Interim Filings and Rule 13a – 15(e) and 15(d) – 15(e) under the United States Securities Exchange Act of 1934.
Under the supervision and with the participation of our CEO and our CFO, management has designed internal control over financial reporting based on the framework set forth in Internal Control – Integrated Framework issued in 2013 by the Committee of Sponsoring Organizations of the Treadway Commission. A material weakness is a deficiency, or a combination of deficiencies, in ICFR, such that there is a reasonable possibility that a material misstatement of the annual financial statements, or interim financial statements, will not be prevented or detected on a timely basis. As at September 30, 2021, the Company has identified a "material weakness" related to controls over contract assessment in its Marketing business. Specifically, we did not have controls to identify all contracts where an accounting assessment was required and as a result lacked analysis of all relevant contract terms required to make the assessment in the Marketing business. Because of the deficiency, the Company presented revenue and cost of goods sold for certain crude contracts in Marketing and New Ventures on a gross basis that should have been recorded on a net basis. Management has appropriately recognized revenue and cost of goods sold for these transactions on a net basis for the three and nine month periods ended September 30, 2021 and has restated revenue and cost of goods sold for the three and nine month periods ended September 30, 2020 with no impact on earnings, cash flows or financial position. Refer to note 2 of the Interim Financial Statements for details of the restatement.

28 Pembina Pipeline Corporation Third Quarter 2021


Remediation of Material Weakness
The control deficiency described above was detected by management during the third quarter of 2021 prior to the filing of Pembina's Interim Financial Statements. The Company has prioritized the remediation of the material weakness described above and is working under the oversight of the Audit Committee to resolve the issue.
Specific actions to remediate this material weakness include the following:
i.Revision of the process of identifying contracts to consult with internal experts to assist in the evaluation of technical accounting matters; and
ii.Enhance contract analysis, including revision of the process used to assess accounting implications for complex contracts.
As the conclusion regarding the material weakness in ICFR was reached in late October 2021, Pembina has not had adequate time to implement and evaluate the controls and procedures described above, as limited complex and material transactions requiring an application of the foregoing remediation actions have occurred in this period. Pembina has, therefore, not had adequate time or opportunity to apply its proposed remediation actions to evidence the remediation of the material weakness described above and the material weakness will continue to be addressed throughout the remainder of 2021.
Changes in Internal Control Over Financial Reporting
Other than the material weakness described above, there were no changes in the third quarter of 2021 that had or are likely to have a material impact on Pembina's ICFR.
Pembina Pipeline Corporation Third Quarter 2021 29


10. ACCOUNTING POLICIES & ESTIMATES
Changes in Accounting Policies & Restatement
The accounting policies used in preparing the Interim Financial Statements are described in Note 5 of Pembina's Consolidated Financial Statements. There were no new accounting standards or amendments to existing standards adopted in the first nine months of 2021 that are expected to have a material impact on Pembina's financial statements.
Voluntary change in accounting policy
As detailed in Note 3 of the Consolidated Financial Statements, Pembina voluntarily changed its accounting policy for the measurement of decommissioning liabilities to utilize a credit-adjusted risk-free interest rate instead of a risk-free interest rate to determine the present value of the liability at each statement of financial position date. This accounting policy change was applied retrospectively, including the restatement of certain comparative amounts in the Interim Financial Statements, as summarized below.
Restatement of revenue and cost of goods sold
During the third quarter Pembina identified certain crude contracts that were recorded incorrectly within Marketing & New Ventures. Revenue and cost of goods sold associated with the contracts were recorded on a gross basis but should have been recorded on a net basis. As a result Pembina restated comparative periods decreasing revenue and cost of goods sold, with no impact to earnings, cash flows or financial position.
i.Reconciliation of the Condensed Consolidated Interim Statements of Earnings and Comprehensive Income

($ millions)
3 Months Ended September 30, 2020 9 Months Ended September 30, 2020
Previously reported Policy change Restatement adjustments Restated Previously reported Policy change Restatement adjustments Restated
Revenue 1,569  —  (73) 1,496  4,508 —  (235) 4,273
Cost of sales 1,068  (4) (73) 991  3,033  (12) (235) 2,786 
Share of profit from equity accounted investees 61  —  62  209  212 
Gross profit 563  —  568  1,746  15  1,761 
Net finance costs 83  (1) —  82  364  (3) 361 
Earnings before income tax 428  —  434  1,213  18  1,231 
Deferred tax expense 58  —  59  133  136 
Earnings attributable to shareholders 318  —  323  885  15  900 
Total comprehensive income attributable to shareholders 214  —  219  1,057  15  1,072 
Earnings attributable to common shareholders, net of preferred share dividends 279  —  284  768  15  783 
Earnings per common share - basic and diluted
0.51 0.01 0.52 1.39 0.03 1.42
ii.Reconciliation of the Condensed Consolidated Interim Statement of Cash Flows

($ millions)
3 Months Ended September 30, 2020 9 Months Ended September 30, 2020
Previously reported Policy change Restated Previously reported Policy change Restated
Earnings 318  323  885  15  900 
Share of profit from equity accounted investees (61) (1) (62) (209) (3) (212)
Adjustments for depreciation and amortization 179  (4) 175  532  (12) 520 
Adjustments for net finance costs 83  (1) 82  364  (3) 361 
Adjustments for income tax expense 110  111  328  331 
Cash flow from operating activities 434  —  434  1,486  —  1,486 
30 Pembina Pipeline Corporation Third Quarter 2021


Critical Accounting Judgments & Estimates
Critical accounting judgments and estimates used in preparing the Interim Financial Statements are described in Note 2 of Pembina's Consolidated Financial Statements. The preparation of consolidated financial statements in conformity with IFRS requires management to make both judgments and estimates that could materially affect the amounts recognized in the financial statements. By their nature, judgments and estimates may change in light of new facts and circumstances in the internal and external environment. There have been no material changes to Pembina's critical accounting estimates and judgments during the three and nine months ended September 30, 2021, including to the ongoing impact of significant uncertainties created by the COVID-19 pandemic, as discussed below.
Ongoing Impact of the COVID-19 Pandemic
Following the World Health Organization declaring the COVID-19 outbreak to be a pandemic, many governments imposed restrictions on individuals and businesses, which resulted in a significant slowdown of the global economy. While there have been positive signals into the first nine months of 2021 in commodity prices, demand recovery remains affected by the on-going COVID-19 pandemic. Although restrictions have been relaxed in certain jurisdictions and vaccination programs are underway, there remains significant uncertainty as to the global economic outlook and there remains the potential for volatility in the global economy as a result of the COVID-19 pandemic. Management considered these uncertainties when applying judgment to estimates and assumptions in the Interim Financial Statements.
Pembina Pipeline Corporation Third Quarter 2021 31


11. RISK FACTORS
Management has identified the primary risk factors that could potentially have a material impact on the financial results and operations of Pembina. With the exception of the risks noted below, there have been no material changes to the risk factors presented in Pembina's MD&A and AIF for the year ended December 31, 2020. Pembina's MD&A and AIF are available at www.sedar.com, www.sec.gov and through Pembina's website at www.pembina.com.
Ongoing Impact of the COVID-19 Pandemic
COVID-19 Related Impacts
Pembina's business and operations have been and may continue to be materially adversely affected by the COVID-19 pandemic, including ongoing uncertainty with respect to the extent and duration of the pandemic. In 2020, the COVID-19 pandemic resulted in, among other things, an overall slowdown in the global economy and a decrease in global energy demand. The ongoing COVID-19 pandemic, and actions that have, and may be, taken by governmental authorities in response thereto has also resulted, and may continue to result in, among other things: increased volatility in financial and commodity markets; disruptions to global supply chains; labour shortages; significant impacts to the workforce; including as a result of the implementation of vaccine mandates and vaccine recommendations; reductions in trade volumes; temporary operational restrictions and restrictions on gatherings of individuals, as well as shelter-in-place declarations and quarantine orders; business closures and travel bans; political and economic instability; and civil unrest. The ongoing spread of the COVID-19 virus, including new variants thereof, in certain geographic areas, including certain areas in which Pembina has operations, and the possibility that a resurgence of the COVID-19 virus or the spread of such new or potential future variants thereof may occur in other areas, may result in the re-imposition of certain of the foregoing restrictions or further restrictions by governmental authorities in certain jurisdictions, including certain jurisdictions in which Pembina has operations. This further increases the risk and uncertainty as to the extent and duration of the COVID-19 pandemic and its ultimate impact on the global economy and other items noted above.
The risks to Pembina of the ongoing COVID-19 pandemic include, among other things: risks to the health and safety of Pembina's employees; a slowdown or temporary suspension of operations in certain geographic locations in which Pembina operates; delays in the completion, or additional deferrals, of Pembina's growth and expansion projects; disruptions in Pembina's workforce, including as a result of vaccine mandates; and supply chain disruptions, all or any of which could materially adversely impact Pembina's business operations and financial results.
The full extent and impact of the COVID-19 pandemic continues to be unknown at this time and the degree to which it may impact Pembina's business operations and financial results will depend on future developments, which cannot be predicted with any degree of certainty, including: the duration, severity and geographic spread of the COVID-19 virus and variants thereof, including in respect of the ongoing spread of the COVID-19 virus, and new variants thereof, in certain geographic areas, including certain areas in which Pembina operates; further actions that may be taken by governmental authorities, including in respect of the implementation of vaccine mandates and ongoing and future operational restrictions and restrictions on travel; the effectiveness and timing of actions taken to contain and treat the COVID-19 virus and variants thereof, including the vaccines developed in response thereto; and how quickly and to what extent normal economic and operating conditions will resume.
Impact on General Risks
Depending on the extent and duration of the COVID-19 pandemic, it may also have the effect of heightening many of the other risks described in Pembina's other disclosure documents, including Pembina's MD&A and AIF for the year ended December 31, 2020, such as risks relating to Pembina's exposure to commodity prices; the successful completion of Pembina's growth and expansion projects, including the expected return on investment thereof; Pembina's ability to maintain its credit ratings; restricted access to capital and increased borrowing costs; Pembina's ability to pay dividends and service obligations under its debt securities and other debt obligations; and otherwise complying with the covenants contained in the agreements that govern Pembina's existing indebtedness.
32 Pembina Pipeline Corporation Third Quarter 2021


12. NON-GAAP MEASURES
Throughout this MD&A, Pembina has used financial measures that are not defined by GAAP but are used by management to evaluate the performance of Pembina and its businesses. Since non-GAAP measures do not have a standardized meaning prescribed by IFRS and are therefore unlikely to be comparable to similar measures presented by other companies, non-GAAP measures must be clearly defined, qualified and reconciled to the most directly comparable GAAP measure. These non-GAAP measures are calculated and disclosed on a consistent basis from period to period.
The intent of the non-GAAP measures used throughout this MD&A is to provide additional useful information with respect to Pembina's financial performance to investors and analysts, though the measures do not have any standardized meaning under IFRS. The measures should not, therefore, be considered in isolation or used in substitute for measures of performance prepared in accordance with IFRS. Other issuers may calculate these non-GAAP measures differently or use different non-GAAP measures.
Investors should be cautioned that net revenue, adjusted EBITDA, adjusted EBITDA per common share, adjusted cash flow from operating activities, cash flow from operating activities per common share, and adjusted cash flow from operating activities per common share should not be construed as alternatives to revenue, earnings, cash flow from operating activities, gross profit or other measures of financial results determined in accordance with GAAP as indicators of Pembina's performance.
Non-GAAP Proportionate Consolidation of Investments in Equity Accounted Investees Results
In accordance with IFRS, Pembina's jointly controlled investments are accounted for using equity accounting. Under equity accounting, the assets and liabilities of the investment are presented net in a single line item in the Consolidated Statement of Financial Position, "Investments in Equity Accounted Investees". Net earnings from investments in equity accounted investees are recognized in a single line item in the Consolidated Statement of Earnings and Comprehensive Income "Share of Profit from Equity Accounted Investees". Cash contributions and distributions from investments in equity accounted investees represent Pembina's share paid and received in the period to and from the investments in equity accounted investees.
To assist in understanding and evaluating the performance of these investments, Pembina is supplementing the IFRS disclosure with non-GAAP proportionate consolidation of Pembina's interest in the investments in equity accounted investees. Pembina's proportionate interest in equity accounted investees has been included in adjusted EBITDA.
Net Revenue
Net revenue is a non-GAAP financial measure which is defined as total revenue less cost of goods sold including product purchases. Management believes that net revenue provides investors with a single measure to indicate the margin on sales before non-product operating expenses that is comparable between periods. Management utilizes net revenue to compare consecutive results in Marketing & New Ventures and Facilities, to aggregate revenue generated by each of the Company's divisions and to set comparable objectives.
3 Months Ended September 30
Pipelines
Facilities
Marketing &
New Ventures
(1)
Corporate &
Inter-segment Eliminations
Total(1)
($ millions)
2021 2020 2021 2020 2021 2020 2021 2020 2021 2020
Revenue 566  557  341  311  1,393  752  (151) (124) 2,149  1,496 
Cost of goods sold, including product purchases
  —  1  1,268  720  (81) (76) 1,188  647 
Net revenue 566  557  340  308  125  32  (70) (48) 961  849 
(1)    Comparative 2020 period has been restated. See "Restatement of Revenue and Cost of Goods Sold" and Note 2 to the Interim Financial Statements.
Pembina Pipeline Corporation Third Quarter 2021 33


9 Months Ended September 30
Pipelines
Facilities
Marketing &
New Ventures
(1)
Corporate &
Inter-segment Eliminations
Total(1)
($ millions)
2021 2020 2021 2020 2021 2020 2021 2020 2021 2020
Revenue 1,673  1,648  1,014  905  3,827  2,074  (447) (354) 6,067  4,273 
Cost of goods sold, including product purchases
  —  7  3,463  2,006  (257) (230) 3,213  1,783 
Net revenue 1,673  1,648  1,007  898  3