Suncor Energy Inc (SU) KPIs and segments

SUNYSEPetroleum RefiningFiscal year ends December 31

Financials through fiscal 2025, year ended Dec 31, 2025Last filing: 40-F on Feb 26, 2026Score 1/30

$69.92+0.63 (+0.91%)

Close on Nov 13, 2026Market cap $83.45BP/E 20.3Yield –

KPIs & segments

Operating metrics and segments that drive Suncor Energy's business · fiscal year ends December 31

Suncor Energy KPIs at a glance: 39 operating metrics, including Total Upstream Production (mbbls/d), Refinery Crude Oil Throughput (mbbls/d) and Refinery Capacity Utilization, drawn from 140 source documents, alongside revenue by segment, product and region from SEC filings. Each figure links to the document it came from. All metrics shows the full sheet; Core narrows it to segments and headline KPIs. The segment tables also offer a trailing-twelve-month view.

The chart is empty. Tick the box next to any metric in the table below to plot it — tick several to compare them on one chart.

Segments, headline KPIs and every operating metric from filings, earnings releases and presentations.

Metric	Q2 2026	Q1 2026	Q4 2025	Q3 2025	Q2 2025	Q1 2025	Q4 2024	Q3 2024	Q2 2024	Q1 2024	Q4 2023	Q3 2023

Total Upstream Production (mbbls/d)2	761	875	909	870	808	853	875	829	771	835	808	691
Total Oil Sands Production — Net of Upgrading Shrinkage (mbbls/d)7	690	799	845	812	748	791	818	776	716	785	757	646
Upgraded Production — Net SCO & Diesel (mbbls/d)3	482	519	557	544	438	537	544	514	462	545	476	469
Oil Sands Operations — Net SCO & Diesel (mbbls/d)	311	379	362	371	281	361	358	330	322	375	289	289
Syncrude Joint Operation — Net SCO & Diesel (58.74% WI, mbbls/d)	199	172	225	201	187	206	215	214	167	198	207	200
Upgraded Inter-Asset Transfers & Internal Consumption (mbbls/d)	-28	-32	-30	-27	-30	-31	-29	-29	-27	-28	-20	-20
Non-Upgraded Bitumen Production (mbbls/d)4	208	280	288	268	310	254	274	262	254	240	282	177
Fort Hills Mine — Marketable Bitumen (100% WI since Nov 2023, mbbls/d)	154	187	178	184	163	176	162	166	167	178	154	86
Oil Sands Operations — Non-Upgraded Bitumen (Firebag & MacKay River, mbbls/d)	120	161	165	150	163	165	181	129	137	120	172	122
Syncrude — Non-Upgraded Bitumen (58.74% WI, mbbls/d)	0	16	0	0	9	0	0	0	4	0	1	0
Non-Upgraded Inter-Asset Transfers (Fort Hills / Firebag / Syncrude, mbbls/d)	-66	-85	-55	-67	-25	-87	-69	-32	-54	-58	-45	-31
Gross Oil Sands Bitumen Mined & Extracted Before Upgrading (mbbls/d)	815	934	993	958	861	937	952	910	834	932	866	787
Operated Upgrader Utilization — Combined Base Plant & Syncrude (%)2
Oil Sands Base Plant Upgrader Utilization (%)(%)	89.0%	108.0%	103.0%	106.0%	80.0%	103.0%	102.0%	94.0%	92.0%	107.0%		94.0%
Syncrude Upgrader Utilization (%)(%)	97.0%	84.0%	109.0%	98.0%	91.0%	100.0%	105.0%	104.0%	81.0%	96.0%		104.0%
Total Oil Sands Sales Volumes (mbbls/d)2	705	797	854	820	748	773	821	765	726	784	735	656
Syncrude Total Production Before Inter-Asset Transfers (58.74% WI, mbbls/d)	199	189	225	201	197	206	215	214	171	198	208	200
Total Oil Sands Inter-Asset Transfers & Consumption (mbbls/d)	-94	-117	-85	-94	-54	-118	-98	-62	-81	-85	-65	-51
Exploration & Production (E&P) Total Production (mbbls/d)3	71	76	64	58	60	62	58	53	55	50	51	44
E&P Canada — East Coast Offshore Crude Oil Production (mbbls/d)	69	71	63	56	56	56	50	53	49	47	45	40
E&P International Production (Libya; UK & Norway Divested 2022–2023, mboe/d)	2	5	1	2	3	7	7	0	6	4	5	5
E&P Total Sales Volumes (mbbls/d)	78	75	52	67	65	55	45	70	47	63	29	43

Refinery Crude Oil Throughput (mbbls/d)	471	498	504	492	442	483	486	488	431	455	456	463
Refinery Capacity Utilization (%)(%)	92.0%	97.0%	99.0%	96.0%	87.0%	94.0%	104.0%	105.0%	92.0%	98.0%	98.0%	99.0%
Refined Product Sales Volumes (mbbls/d)4	655	681	640	647	601	605	613	612	595	581	576	574
Transportation Fuels Sales Subtotal (mbbls/d)2	557	587	547	552	521	525
Distillate & Diesel Sales (mbbls/d)	307	318	273	290	270	263
Gasoline Sales (mbbls/d)	250	269	274	262	251	263
Asphalt Sales (mbbls/d)	36	26	29	45	31	25
Petrochemicals Sales (mbbls/d)	4	11	4	3	4	7
Other Refined Products Sales (mbbls/d)	58	57	60	47	44	47
Rack Forward Retail & Commercial Sales Volume (million litres, ML)	5,713	5,659	5,883	6,040	5,724	5,419	5,609	5,955	5,592	5,108	5,286	5,445
Refining & Marketing Gross Margin — LIFO Basis (C$/bbl)($)5	61.50	48.25	45.15	39.55	34.40	38	30.60	35.85	36.35	45.75	47.05	42.45
Refining & Marketing Gross Margin — FIFO Accounting Basis (C$/bbl)($)	69.65	59.10	40.75	39.65	32.45	36.70	30	32.25	37.65	46.65	37.45	50.10
Refining & Marketing Custom 5-2-2-1 Margin Capture (%)(%)	89.0%	99.0%	101.0%	92.0%	89.0%	99.0%	90.0%
Refining Unit Operating Expense (C$/bbl)($)	6.35	6.75	6.55	6	6.85	6.75	6.55	5.80	6.95	7.15	7.65	6.20
Rack Forward Marketing Gross Margin (Canadian cents/litre, cpl)($)	3.15	5.20	6.85	4.35	6.15	6.45	7.35	7.30	6.25	5	6.90	5.95
Rack Forward Marketing Operating Expense (Canadian cents/litre, cpl)($)	3	3.15	3.10	2.65	2.80	3.15	3.45	3.10	3.10	3.20	4.20	3.10

Oil Sands Operations Cash Operating Costs — Base Plant, Firebag & MacKay River (C$/bbl)($)3	32.70	28.95	25.90	24.85	27.95	27.80	26.55	25.75	28.45	26.85	30.80	29.15
Cash Costs Component Excl. Natural Gas (C$/bbl)($)	30.65	26.25	23.05	23.80	25.45	25.20	24.95	24.80	26.90	24.55	28.30	27
Natural Gas Energy Component (C$/bbl)($)	2.05	2.70	2.85	1.05	2.50	2.60	1.60	0.95	1.55	2.30	2.50	2.15
Oil Sands Operations Total Cash Operating Costs (C$M)(M)2	1,281	1,405	1,256	1,193	1,126	1,317	1,315	1,085	1,188	1,210	1,306	1,100
Cash Costs Component (C$M)(M)	1,200	1,273	1,119	1,142	1,024	1,194	1,235	1,045	1,123	1,107	1,199	1,020
Natural Gas Component (C$M)(M)	81	132	137	51	102	123	80	40	65	103	107	80
Fort Hills Cash Operating Costs (C$/bbl)($)3	44.50	34.10	31.60	30.65	36.75	33.85	34.25	33.40	30.60	32.85	28.10	43.40
Fort Hills Cash Costs Excl. Natural Gas (C$/bbl)($)	43.30	32.75	30.10	30.10	35.65	32.35	33.15	32.80	29.80	31.20	26.95	41.80
Fort Hills Natural Gas Component (C$/bbl)($)	1.20	1.35	1.50	0.55	1.10	1.50	1.10	0.60	0.80	1.65	1.15	1.60
Fort Hills Total Cash Operating Costs (C$M)(M)2	625	574	518	520	544	538	510	510	465	531	398	344
Fort Hills Cash Costs (C$M)(M)	608	551	494	511	528	514	493	501	453	505	382	331
Fort Hills Natural Gas Costs (C$M)(M)	17	23	24	9	16	24	17	9	12	26	16	13
Syncrude Cash Operating Costs (58.74% WI, C$/bbl)($)3	40.15	42.20	31.05	31.45	36.50	36.10	32.80	33	40.15	35.70	33.85	33.15
Syncrude Cash Costs Excl. Natural Gas (C$/bbl)($)	39.45	41	30.15	31.15	35.60	35.25	32.20	32.70	39.50	34.45	32.85	32.20
Syncrude Natural Gas Component (C$/bbl)($)	0.70	1.20	0.90	0.30	0.90	0.85	0.60	0.30	0.65	1.25	1	0.95
Syncrude Total Cash Operating Costs (C$M)(M)2	728	716	643	581	652	670	649	649	625	642	648	609
Syncrude Cash Costs (C$M)(M)	715	696	624	576	636	654	637	643	615	620	629	592
Syncrude Natural Gas Costs (C$M)(M)	13	20	19	5	16	16	12	6	10	22	19	17
Total Oil Sands Weighted Average Operating Netback (C$/bbl)($)4	68.62	45.69	34.06	41.46	35.30	45.37	43.97	48.31	50.32	41.30	41.97	50.83
Average Price Realized (C$/bbl)($)	130	93.41	75	85.48	80.98	92.54	90.96	95.49	102	87.34	89.56	106
Royalties (C$/bbl)($)	-19.07	-9.93	-7.90	-11.66	-8.76	-11.71	-12.43	-13.14	-15.14	-10.96	-9.49	-18.42
Transportation & Distribution (C$/bbl)($)	-4.61	-4.78	-4.14	-4.68	-4.92	-4.26	-4.64	-4.13	-4.42	-4.10	-5.84	-4.21
Net Operating Expenses (C$/bbl)($)	-37.29	-33.01	-28.90	-27.68	-32	-31.20	-29.92	-29.91	-32.02	-30.98	-32.26	-33
Upgraded — Net SCO & Diesel Operating Netback (C$/bbl)($)4	76.35	47.35	38.48	43.89	37.78	47	47.39	52.86	50.96	45.29	46.56	50.21
Non-Upgraded Bitumen Operating Netback (C$/bbl)($)4	51.57	42.73	25.18	36.71	31.76	41.88	37.46	39.18	49.23	31.96	34.44	52.45

Adjusted Funds From Operations — AFFO (C$M)(M)6	5,329	4,030	3,218	3,831	2,689	3,045	3,493	3,787	3,397	3,169	4,034	3,634
Oil Sands Segment AFFO (C$M)(M)	3,819	2,894	2,406	2,900	2,399	2,810	3,126	3,165	3,108	2,443	2,651	2,929
Refining & Marketing Segment AFFO (C$M)(M)	2,299	1,981	1,174	1,216	615	902	638	701	893	1,306	811	1,482
Exploration & Production Segment AFFO (C$M)(M)	652	562	214	279	372	330	274	471	398	467	228	372
Corporate & Eliminations AFFO (C$M)(M)	-123	-630	-108	-152	-285	-349	-131	71	-221	-398	10	-368
Current Income Tax Expense Included in AFFO (C$M)(M)	-1,318	-777	-468	-412	-412	-648	-414	-621	-781	-649	334	-781
AFFO per Common Share — Basic (C$/sh)($)	4.52	3.39	2.68	3.16	2.20	2.46	2.78	2.98	2.65	2.46	3.12	2.80
Capital & Exploration Expenditures — Excl. Capitalized Interest (C$M)(M)7	1,349	1,117	1,519	1,484	1,708	1,145	1,570
Oil Sands Capital Expenditures (C$M)(M)	914	746	1,013	998	1,109	749	941
Refining & Marketing Capital Expenditures (C$M)(M)	300	232	316	290	362	180	352
Exploration & Production Capital Expenditures (C$M)(M)	126	128	177	182	229	209	255
Corporate & Eliminations Capital Expenditures (C$M)(M)	9	11	13	14	8	7	22
Asset Sustainment & Maintenance CapEx Total (C$M)(M)5	828	580	815
Economic Investment (Growth) CapEx Total (C$M)(M)6	482	496	668
Capitalized Interest (C$M)(M)	39	41	36
Free Funds Flow (C$M)(M)5	3,980	2,913	1,699	2,347	981	1,900	1,923	2,232	1,350	1,858	2,482	2,057
Oil Sands Segment Free Funds Flow (C$M)(M)	2,905	2,148	1,393	1,902	1,290	2,061	2,185	2,198	1,671	1,448	1,583	1,754
Refining & Marketing Segment Free Funds Flow (C$M)(M)	1,999	1,749	858	926	253	722	286	406	518	1,138	506	1,287
Exploration & Production Segment Free Funds Flow (C$M)(M)	526	434	37	97	143	121	19	190	169	325	67	185
Corporate & Eliminations Free Funds Flow (C$M)(M)	-132	-641	-121	-166	-293	-356	-153	59	-227	-404	-8	-388
Free Funds Flow per Common Share (C$/sh)($)	3.38	2.45	1.42	1.94	0.80	1.53	1.53	1.76	1.05	1.44	1.92	1.58
Net Debt — Excl. Lease Liabilities from 2024 Definition (C$M)(M)3	4,481	6,842	6,337	7,147	7,673	7,559	6,861	7,968	9,054	9,552	9,852	9,837
Total Short-Term & Long-Term Debt (C$M)(M)	9,853	10,113	9,987	10,091	9,942	10,332	10,345	10,973	11,428	15,949	15,407	15,427
Cash & Cash Equivalents (C$M)(M)	5,372	3,271	3,650	2,944	2,269	2,773	3,484	3,005	2,374
Return on Capital Employed — ROCE (%)(%)	18.3%	12.4%	11.3%	11.0%	11.1%	12.8%	13.0%	15.6%	15.6%	15.7%	16.3%	16.5%
Total Cash Returned to Shareholders — Dividends + Share Buybacks (C$M)(M)5	1,756	1,537	1,494	1,438	1,447	1,455	1,713	1,480	1,523	995	1,079	976
Cash Dividends Paid on Common Shares (C$M)(M)	706	712	719	688	697	705	713	690	698	702	704	676
Dividends Paid per Common Share (C$/sh)($)	0.60	0.60	0.60	0.57	0.57	0.57	0.57	0.55	0.55	0.55	0.55	0.52
Common Share Repurchases Executed (C$M)(M)	1,050	825	775	750	750	750	1,000	790	825	293	375	300
Common Shares Repurchased & Cancelled (thousand shares)	12,018	11,072	13,129	13,600	14,993	13,600	18,521	15,044	15,561	6,438	8,453	6,789
Weighted Average Share Repurchase Price (C$/share)($)	87.38	74.51	59.03	55.15	50.03	55.15	53.99	52.51	53	45.53	44.37	44.20

WTI Crude Oil at Cushing — Suncor Quarterly Average (US$/bbl)($)13	92.85	72.15	59.15	64.95	63.70	71.40	70.30	75.15	80.55	76.95	78.35	82.20
Brent Crude Oil at Sullom Voe (US$/bbl)($)	105	80.95	63.70	69.10	67.80	75.70	74.70	80.25	84.90	83.25	84.05	86.70
Western Canadian Select (WCS) at Hardisty (US$/bbl)($)	78.20	58	47.95	54.55	53.50	58.75	57.75	61.65	67	57.60	56.45	69.30
WCS – WTI Heavy Differential (US$/bbl)($)	-14.65	-14.15	-11.20	-10.40	-10.20	-12.65	-12.55	-13.50	-13.55	-19.35	-21.90	-12.90
SYN (Sweet Synthetic Crude) – WTI Differential (US$/bbl)($)	8.40	-0.40	-1.30	1.35	1	-2.35	0.85	1.30	2.80	-7.40	0.30	2.80
Mixed Sweet Blend (MSW) Light Crude at Edmonton (C$/bbl)($)	132	93.85	76.55	86.40	84.25	95.30	94.95	98	105	92.20	99.70	108
C5+ Condensate Diluent at Edmonton (US$/bbl)($)	95.55	71.65	57	63.10	63.50	69.90	70.65	71.30	77.15	72.80	76.25	77.90
AECO-C Natural Gas Spot Benchmark (C$/GJ)($)	1.55	1.90	2.20	0.60	1.65	2.05	1.45	0.65	1.10	2.20	2.15	2.50
Suncor Custom 5-2-2-1 Refining Benchmark Index (US$/bbl)($)	50.10	35.70	32	31.20	27.85	26.80	24.25	26.05	26.70	35.95	33.45	36
New York Harbor 2-1-1 Refining Crack Spread (US$/bbl)($)	55.55	35.40	29.90	29.95	25.90	21.05	18.80	21.05	24.75	27.05	28.60	39.95
Chicago 2-1-1 Refining Crack Spread (US$/bbl)($)	51	23.05	21.50	26.40	22.05	14.65	13.85	19.35	18.85	19.80	17.10	27.45
Portland 2-1-1 Refining Crack Spread (US$/bbl)($)	63.35	38.25	31.75	42.05	38.20	22.30	20.95	20.35	29.30	26.85	29.35	55.90
U.S. Gulf Coast 2-1-1 Refining Crack Spread (US$/bbl)($)	51.55	32.55	27.15	27.10	23.20	20.85	17	18.90	22.10	27.95	23	39.10
Exchange Rate Average — US$ per C$1.00 (US$/Cdn$)(×)	0.72	0.73	0.72	0.73	0.72	0.70	0.71	0.73	0.73	0.74	0.73	0.75

Oil Sands Segment Earnings (Loss) Before Income Taxes (C$M, DB + Form 6-K)(M)3	2,691	1,516	1,120	1,638	844	1,675	1,625	1,819	1,792	1,371	2,660	1,407
Consolidated Adjusted Operating Earnings — Non-GAAP (C$M, Form 6-K)(M)5	3,804	2,300	1,325	1,794	873	1,629	1,566	1,875	1,626	1,817	1,635	1,980
Consolidated Net Revenue (C$M, PostgreSQL DB)3

Italic numbers are calculated by StockData from reported figures (hover for the formula). Numbers with a dotted underline are read from the text of earnings releases and presentations; hover to see the exact sentence. Tick a row to add it to the chart above (up to 8 lines).

Methodology and excluded metrics

Core rows come from the segment and revenue-disaggregation notes of 10-K and 10-Q filings (XBRL), linked to each filing. Fourth-quarter figures are the fiscal year less the first nine months (shown in italic).
Suncor Energy Inc. (TSX / NYSE: SU) reports under IFRS in Canadian dollars (C$). Its latest reported quarter is Q2 2026 (ended June 30, 2026) and latest completed fiscal year is FY2025; the 2026 annual column holds Suncor's official 2026 Corporate Guidance ranges (Form 6-K filed December 11, 2025) and 2026 TSX Normal Course Issuer Bid limit (118.7M shares).
Leading monthly regulatory telemetry comes directly from two Canadian government regulators: (1) Alberta Energy Regulator (AER) ST39 Mineable Oil Sands Monthly Supplement through July 2026 (Suncor Base Plant, Fort Hills, Syncrude Mildred Lake, and Syncrude Aurora North) and ST53 In Situ Thermal Summary through August 2026 (Firebag and MacKay River SAGD bitumen, steam, SOR, and well counts), and (2) Canada-Newfoundland & Labrador Offshore Energy Regulator (C-NLOER) monthly field statistics through September 2026 (full Q3 2026 actuals for Hebron, Hibernia, Terra Nova, and White Rose).
Effective January 1, 2026, Suncor increased total refining network nameplate capacity by 10% from 466.0 mbbls/d to 511.0 mbbls/d and restated 2025 refinery utilization comparatives on the higher capacity base (FY2025 restated from 103% to 94%). Beginning Q1 2026, Suncor also aggregated quarterly Eastern and Western North America downstream disclosures.
On October 5, 2026 (Form 6-K 0001104659-26-114174), Suncor agreed to sell its 48% operated interest in Terra Nova, 40% interest in White Rose, and 38.6% interest in West White Rose to Ithaca Energy for C$1.2B upfront cash + up to C$350M contingent payments (retaining Hebron 21.03% WI and Hibernia 20.0% WI), and simultaneously increased monthly NCIB share buybacks to C$750M/month starting October 2026.
Because Suncor files quarterly interim reports on SEC Form 6-K HTML without inline XBRL, PostgreSQL DB contains only annual FY2015–FY2025 income, cash-flow, and segment records; Group 9 pairs annual PostgreSQL DB series with 22–42 quarters of Form 6-K disclosures.
Canadian IFRS consolidated filings do not publish standalone parent-only financial statements, and Suncor has no separately listed operating subsidiary, so consolidated − standalone parent subtraction is not applicable.
Following June 2024 Competition Act (Canada) Bill C-59 amendments, Suncor removed quantitative GHG emissions/intensity tables from its sustainability disclosures and `www.suncor.com` blocks automated requests via Cloudflare Turnstile (HTTP 403); safety rates, workforce, reserves, and Form SD XBRL government payments are sourced directly from official SEC filings.
All values are exact published figures from SEC filings, PostgreSQL DB, AER, C-NLOER, or FRED, with zero custom ratio, sum, or unit-conversion formulas.

Not shown because recent periods are missing (3)

Upstream Production, Asset Mix, Upgrader Utilization & Corporate Guidance (Core Key) › Total Upstream Production (mbbls/d) › Total Oil Sands Production — Net of Upgrading Shrinkage (mbbls/d) › Gross Oil Sands Bitumen Mined & Extracted Before Upgrading (mbbls/d) › Firebag Quarterly Standalone Production — Legacy Pre-2020Q2 Disclosure (mbbls/d)
Upstream Production, Asset Mix, Upgrader Utilization & Corporate Guidance (Core Key) › Total Upstream Production (mbbls/d) › Total Oil Sands Production — Net of Upgrading Shrinkage (mbbls/d) › Gross Oil Sands Bitumen Mined & Extracted Before Upgrading (mbbls/d) › MacKay River Quarterly Standalone Production — Legacy Pre-2020Q2 Disclosure (mbbls/d)
Upstream Production, Asset Mix, Upgrader Utilization & Corporate Guidance (Core Key) › Total Upstream Production (mbbls/d) › Exploration & Production (E&P) Total Production (mbbls/d) › E&P Canada — East Coast Offshore Crude Oil Production (mbbls/d) › Buzzard UK North Sea — Divested June 2023 (mbbls/d, Legacy AIF)

Data updated 2026-11-01.

Every KPI on its own page

Full history, chart, sources and a citation for each metric

Upstream Production, Asset Mix, Upgrader Utilization & Corporate Guidance (Core Key)

Total Upstream Production (mbbls/d)20 periods

Downstream Refining, Rack Forward Marketing & Petro-Canada Network

Upstream Cash Operating Costs & Operating Netback Waterfalls (C$/bbl)

Leading Monthly Regulatory Production — Alberta AER & Newfoundland Offshore C-NLOER

Capital Expenditures, AFFO, Free Funds Flow, Net Debt & Shareholder Returns

Oil & Gas Reserves & Discounted Future Cash Flows (NI 51-101 & FASB ASC 932)

Workforce, Operational Safety & Extractive Payments to Governments (Form SD XBRL)

Commodity, Crack Spread & Foreign Exchange Benchmarks (Suncor MD&A + Monthly FRED)

Segmented & Consolidated Financial Context (PostgreSQL DB + Form 6-K)

Latest source documents

The documents cited most often for Suncor Energy's most recent figures

See a number that looks wrong?