Diamondback Energy, Inc. (FANG) operating KPIs

FANGNasdaqCrude Petroleum & Natural GasFiscal year ends December 31

Financials through Q2 FY2026, quarter ended Jun 30, 2026Last filing: 10-Q on Aug 5, 2026Score 9/3072% above fair value

$212.08+5.65 (+2.74%)

Close on Oct 30, 2026Market cap $59.39BP/E 41.1Yield 1.89%

KPIs

Operating metrics that drive Diamondback Energy's business · fiscal year ends December 31

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Metric	Q3 2026 2026-09-30	Q2 2026 2026-06-30	Q1 2026 2026-03-31	Q4 2025 2025-12-31	Q3 2025 2025-09-30	Q2 2025 2025-06-30	Q1 2025 2025-03-31	Q4 2024 2024-12-31	Q3 2024 2024-09-30	Q2 2024 2024-06-30	Q1 2024 2024-03-31	Q4 2023 2023-12-31

Total Combined Production (BOE/d)1		1,017,659	979,356	969,120	942,946	919,879	850,656	883,424	571,098	474,670	461,110	462,565
Daily Oil Production (BO/d)		525,176	520,989	512,761	503,750	495,692	475,944	475,924	321,054	276,143	273,341	273,087
Total Combined Production Volume (MBOE)3		92,607	88,142	89,159	86,751	83,709	76,559	81,275	52,541	43,195	41,961	42,556
Crude Oil Production Volume (MBbls)		47,791	46,889	47,174	46,345	45,108	42,835	43,785	29,537	25,129	24,874	25,124
Natural Gas Production Volume (MMcf)		128,279	118,402	121,805	115,353	110,119	100,578	107,249	66,519	51,310	50,602	50,497
Natural Gas Liquids Production Volume (MBbls)		23,436	21,519	21,684	21,180	20,248	16,961	19,615	11,918	9,514	8,653	9,016
Midland Basin — Total Production (MBOE)3		85,147	79,860	81,029	80,824	77,315	70,167	72,284	43,466	34,833	32,947	33,387
Midland Basin — Oil Production (MBbls)		44,209	42,907	43,224	42,979	41,639	39,341	39,134	24,819	20,867	20,055	20,211
Midland Basin — Natural Gas Production (MMcf)		115,656	104,171	107,011	107,507	100,981	90,341	93,596	53,087	38,399	37,494	36,997
Midland Basin — NGL Production (MBbls)		21,662	19,591	19,970	19,927	18,846	15,769	17,551	9,799	7,566	6,643	7,010
Delaware Basin — Total Production (MBOE)3		7,365	7,671	7,296	5,850	6,271	6,275	8,864	9,039	8,324	8,907	9,115
Delaware Basin — Oil Production (MBbls)		3,565	3,721	3,640	3,322	3,417	3,460	4,603	4,706	4,248	4,768	4,886
Delaware Basin — Natural Gas Production (MMcf)		12,242	12,878	12,195	7,807	8,785	9,961	13,318	13,322	12,818	12,894	13,413
Delaware Basin — NGL Production (MBbls)		1,760	1,804	1,623	1,227	1,390	1,155	2,041	2,113	1,940	1,990	1,993
Other Basins — Total Production (MBOE)3		95	611	834	77	123	117	127	36	38	107	55
Other Basins — Oil Production (MBbls)		17	261	310	44	52	34	48	12	14	51	27
Other Basins — Natural Gas Production (MMcf)		381	1,353	2,599	39	353	276	335	110	93	214	87
Other Basins — NGL Production (MBbls)		14	124	91	26	12	37	23	6	8	20	13

Operated Horizontal Wells Completed (Turned to Production) — Gross3		168	147	127	137	116	123	128	95	86	101	59
Midland Basin — Gross Operated Wells Completed9		168	147	127	137	108	116	124	87	79	101	50
Lower Spraberry — Gross Wells Completed		31	32	32	28	21	28	26	21	21	30	14
Wolfcamp A (Midland) — Gross Wells Completed		38	31	22	27	11	30	26	22	20	19	14
Wolfcamp B (Midland) — Gross Wells Completed		41	30	22	27	31	22	24	14	16	15	13
Jo Mill — Gross Wells Completed		31	31	20	26	11	17	19	15	9	16	9
Middle Spraberry — Gross Wells Completed		13	7	19	11	13	8	15	12	10	12	3
Dean — Gross Wells Completed		5	6	4	10	8	4	4	4	5
Wolfcamp D (Midland) — Gross Wells Completed		7	8	4	1	3	3	4		3	6	2
Upper Spraberry — Gross Wells Completed		1	2	2	3	8	2	3	3		3
Barnett — Gross Wells Completed		1	0	2	4	2	4	3		1
Operated Horizontal Wells Completed — Net1		157	137	121	127	109	119	117	102	78	89	53
Midland Basin — Net Wells Completed		157	137	121	127	103	112	113	95	72	89	45
Average Completed Lateral Length (feet)		11,983	11,332	12,474	11,020		11,978	11,810	12,238	11,203	11,463	11,457
Operated Horizontal Wells Drilled (Spud) — Gross2		97	118	107	108	122	126	137	76	80	79	84
Midland Basin — Gross Operated Wells Drilled9		97	118	107	107	121	124	131	71	71	69	80
Lower Spraberry — Gross Wells Drilled		16	24	20	19	27
Wolfcamp A (Midland) — Gross Wells Drilled		20	26	24	28	24
Wolfcamp B (Midland) — Gross Wells Drilled		16	29	22	25	26
Jo Mill — Gross Wells Drilled		22	16	18	19	26
Middle Spraberry — Gross Wells Drilled		6	7	12	7	9
Dean — Gross Wells Drilled		1	1	5	1	5
Wolfcamp D (Midland) — Gross Wells Drilled		7	11	5	4	1
Upper Spraberry — Gross Wells Drilled		2	1	1	1	1
Barnett — Gross Wells Drilled		7	3	0	3	2
Operated Horizontal Wells Drilled — Net1		89	111	100	98	114	118	129	71	75	76	73
Midland Basin — Net Wells Drilled		89	111	100	97	113	116	124	67	67	67	70
Total Operated Producing Wells at Period-End — Gross3		10,040	9,923	9,829	9,802	9,882	9,459	7,942	7,977	5,756	5,710	5,628
Operated Horizontal Wells — Gross2		5,636	5,471	5,342	5,260	5,114	4,876	4,723	4,644	3,138	3,052	2,950
Midland Basin — Operated Horizontal Wells (Gross)		5,179	5,013	4,868	4,744	4,599	4,369	4,102	3,948	2,450	2,371	2,269
Delaware Basin — Operated Horizontal Wells (Gross)		457	458	474	516	515	507	621	696	688	681	681
Operated Vertical Wells — Gross2		4,404	4,452	4,487	4,542	4,768	4,583	3,219	3,333	2,618	2,658	2,678
Midland Basin — Operated Vertical Wells (Gross)		4,368	4,412	4,447	4,437	4,598	4,411	3,066	3,262	2,581	2,621	2,641
Delaware Basin — Operated Vertical Wells (Gross)		36	40	40	105	170	172	153	45	37	37	37
Total Operated Producing Wells at Period-End — Net4		9,478	9,358	9,265	9,227	9,287	8,902	7,463	7,508	5,337	5,326	5,255
Operated Horizontal Wells — Net		5,294	5,126	5,001	4,918	4,778	4,569	4,425	4,354	2,861	2,811	2,721
Operated Vertical Wells — Net		4,184	4,232	4,264	4,309	4,509	4,333	3,038	3,154	2,476	2,515	2,534
Midland Basin — Total Operated Wells (Net)		9,021	8,895	8,789	8,657	8,661	8,281	6,752	6,796	4,669	4,658	4,587
Delaware Basin — Total Operated Wells (Net)		457	463	476	570	626	621	711	691	668	668	668

Midland Basin — Total Oil, Gas & NGL Revenue ($M)($M)3		4,429	3,518	2,777	3,206	3,050	3,366	3,098	1,994	1,789	1,674	1,723
Midland Basin — Oil Sales ($M)($M)		4,289	3,183	2,516	2,786	2,626	2,801	2,726	1,823	1,659	1,503	1,541
Midland Basin — Natural Gas Liquid Sales ($M)($M)		407	324	272	340	335	374	335	179	128	137	137
Midland Basin — Natural Gas Sales ($M)($M)		-267	11	-11	80	89	191	37	-8	2	34	45
Delaware Basin — Total Oil, Gas & NGL Revenue ($M)($M)3		354	287	234	239	246	287	370	360	383	422	440
Delaware Basin — Oil Sales ($M)($M)		337	247	202	206	206	236	313	336	338	360	378
Delaware Basin — Natural Gas Liquid Sales ($M)($M)		28	33	22	26	32	31	43	33	42	47	43
Delaware Basin — Natural Gas Sales ($M)($M)		-11	7	10	7	8	20	14	-9	3	15	19
Other Basins — Total Oil, Gas & NGL Revenue ($M)($M)3		3	20	22	2	20	4	3	0	2	5	2
Other Basins — Oil Sales ($M)($M)		1	15	18	2	20	2	3	1	1	4	1
Other Basins — Natural Gas Liquid Sales ($M)($M)		0	2	-1	0	0	1	0	-1	1	0	0
Other Basins — Natural Gas Sales ($M)($M)		2	3	5	0	0	1	0	0	0	1	1
Total Disaggregated Oil, Gas & NGL Revenue Across All Basins ($M)($M)		4,786	3,825	3,033	3,447	3,316	3,657	3,471	2,354	2,174	2,101	2,165

Combined Average Realized Price — Unhedged ($/BOE)($)3		51.68	43.40	34.02	39.73	39.61	47.77	42.71	44.80	50.33	50.07	50.87
Oil Realized Price — Unhedged ($/Bbl, through Q3 2026)($)		96.82	73.47	58	64.60	63.23	70.95	69.48	73.13	79.51	75.06	76.42
Natural Gas Liquids Realized Price — Unhedged ($/Bbl, through Q3 2026)($)		18.56	16.68	13.51	17.28	18.13	23.94	19.27	17.70	17.97	21.26	19.96
Natural Gas Realized Price — Unhedged ($/Mcf, through Q3 2026)($)		-2.15	0.18	0.03	0.75	0.88	2.11	0.48	-0.26	0.10	0.99	1.29
Combined Average Realized Price — Hedged ($/BOE)($)3		52.90	45.21	34.88	40.58	39.89	48.89	42.76	45.43	50.89	49.97	50.40
Oil Realized Price — Hedged ($/Bbl, through Q3 2026)($)		94.33	72.53	57.07	63.70	62.34	70.06	68.72	72.32	78.55	74.13	75.59
Natural Gas Liquids Realized Price — Hedged ($/Bbl, through Q3 2026)($)		18.56	16.68	13.51	17.28	18.13	23.94	19.27	17.70	17.97	21.26	19.96
Natural Gas Realized Price — Hedged ($/Mcf, through Q3 2026)($)		-0.34	1.90	1.03	1.75	1.45	3.34	0.82	0.60	1.03	1.36	1.31
Total Cash Operating Expense ($/BOE)($)4		10.96	11.26	10.31	10.05	10.10	10.48	10.30	11.49	11.67	11.52	10.83
Lease Operating Expenses — LOE ($/BOE)($)		5.96	6.21	5.91	5.65	5.26	5.33	5.67	6.01	5.88	6.08	5.97
Production and Ad Valorem Taxes ($/BOE)($)		3.26	3.04	2.21	2.44	2.56	2.98	2.77	2.91	3.26	2.84	2.44
Gathering, Processing and Transportation — GPT ($/BOE)($)		1.22	1.36	1.54	1.41	1.73	1.45	1.17	1.94	1.90	1.84	1.83
General and Administrative — Cash Component ($/BOE)($)		0.52	0.65	0.65	0.55	0.55	0.72	0.69	0.63	0.63	0.76	0.59
Total General and Administrative Expense ($/BOE)1
General and Administrative — Non-Cash Stock Compensation ($/BOE)($)		0.26	0.25	0.22	0.25	0.25	0.24	0.20	0.30	0.44	0.34	0.33
Net Interest Expense ($/BOE)($)		0.60	0.71	0.87	0.81	0.67	0.52	0.42	0.34	1.02	0.93	0.68

Total Cash Capital Expenditures ($M)($M)2		996	933	943	774	864	942	933	688	637	609	649
Operated Drilling & Completion CapEx ($M)($M)		842	784	748	632			832	631
Capital Workovers, Non-Operated Properties & Science / Other CapEx ($M)($M)		154	149	130	94			2	2
Free Cash Flow (Operating Cash Flow Before Working Capital Less Cash CapEx, $M)($M)2		2,330	1,705	1,002	1,760	1,242	1,545	1,327	708	816	791	910
Adjusted Free Cash Flow ($M)($M)		2,331	1,737	1,183	1,792	1,334	1,583	1,357	1,003	841		910
Operating Cash Flow Before Working Capital Changes ($M)($M)		3,326	2,638	1,945	2,534	2,106	2,487	2,260	1,396	1,453	1,400	1,559
Consolidated Adjusted EBITDA ($M)($M)2		3,940	3,001	2,254	2,638	2,442	2,947	2,622	1,760	1,678	1,633	1,670
Adjusted EBITDA Attributable to Diamondback Energy, Inc. ($M)($M)		3,549	2,704	2,021	2,408	2,311	2,801	2,504	1,656	1,575	1,547	1,588
Less: Adjusted EBITDA Attributable to Non-Controlling Interest ($M)($M)		391	297	233	230	131	146	118	104	103	86	82
Consolidated Net Debt ($M)($M)4		12,304	13,894	14,563	15,893	15,098	12,283	12,999	12,744	5,268	5,876	6,208
Consolidated Principal Total Debt ($M)($M)		12,766	14,068	14,667	16,432	15,317	14,099	13,160	13,114	12,176	6,772	6,790
Diamondback Energy, Inc. Standalone Principal Debt ($M)($M)		11,071	12,448	12,462	13,792	14,212	13,269	12,069	12,284	11,169	5,669	5,697
Viper Energy, Inc. Subsidiary Principal Debt ($M)($M)		1,695	1,620	2,205	2,640	1,105	830	1,091	830	1,007	1,103	1,093
Consolidated Cash & Cash Equivalents ($M)($M)		462	174	104	539	219	1,816	161	370	6,908	896	582
Shares Repurchased Under Buyback Program (thousand shares)2		756	3,267	2,904	4,286	2,992	3,656	2,326	2,920		279	873
Average Price Paid Per Repurchased Share ($/sh)($)		187	168	149	141	133	157	173	176	193	163	148
Remaining Share Repurchase Authorization at Period-End ($M)($M)		1,976	2,117	2,665	3,099	1,702	2,100	2,675	3,077	1,592	1,592	1,634

Quarterly Oil Production Guidance — Low Bound (MBO/d, through Q3 2026)1	517	515	502	505	485	485	470	470	271	271	270	269
Quarterly Oil Production Guidance — High Bound (MBO/d, through Q3 2026)	527	525	512	515	495	500	475	475	275	275	274	273
Quarterly Total Production Guidance — Low Bound (MBOE/d, through Q3 2026)1	995	950	930	927	890	866	860	840	459	459	458	455
Quarterly Total Production Guidance — High Bound (MBOE/d, through Q3 2026)	1,015	990	966	963	920	900	875	850	466	466	464	460

Viper Energy — Daily Oil Royalty Production (BO/d)4		65,077	65,000	66,413	56,087	41,615	31,311	29,859	26,978	26,352	25,407	24,533
Viper Energy — Total Combined Royalty Production (MBOE)		134,363	130,711	134,000	108,859	79,286	57,378	56,109	49,370	47,473	46,132	43,783
Viper Energy — Oil Royalty Production (MBbls)		5,922	5,850	6,110	5,160	3,787	2,818	2,747	2,482	2,398	2,312	2,257
Viper Energy — Natural Gas Liquids Royalty Production (MBbls)		3,147	2,899	2,940	2,412	1,739	1,142	1,209	1,035	983	954	884
Viper Energy — Natural Gas Royalty Production (MMcf)		18,949	18,088	19,668	14,655	10,132	7,221	7,236	6,150	5,631	5,589	5,321
Viper Energy — Horizontal Producing Well Count on Royalty Acreage (Gross)4		25,560	24,622	24,034	34,682	14,895	15,271	11,059	10,724	9,452	11,586	11,277
Diamondback-Operated Producing Wells on Viper Acreage (Gross)		4,485	4,209	4,092	4,047	3,795	3,725	2,898	2,755	1,964	1,913	1,844
Third-Party-Operated Producing Wells on Viper Acreage (Gross)		21,075	20,413	19,942	30,635	11,100	11,546	8,161	7,969	7,488	9,673	9,433
Viper Producing Wells — Net 100% Royalty Interest Wells (Total)2		601	584	569	633	403	400	260	252	232	242	235
Diamondback-Operated Producing Wells — Net 100% Royalty Interest		278	267	258	255	238	235	156	150	135	132	128
Third-Party-Operated Producing Wells — Net 100% Royalty Interest		323	317	311	377	165	165	104	102	97	110	108
Viper Producing Wells — Average % Net Royalty Interest (Total)(%)2		2.3%	2.4%	2.4%	1.8%	2.7%	2.6%	2.4%	2.4%	2.4%	2.1%	2.1%
Diamondback-Operated Producing Wells — Average % NRI(%)		6.2%	6.3%	6.3%	6.3%	6.3%	6.3%	5.4%	5.4%	6.9%	6.9%	6.9%
Third-Party-Operated Producing Wells — Average % NRI(%)		1.5%	1.6%	1.6%	1.2%	1.5%	1.4%	1.3%	1.3%	1.3%	1.1%	1.1%
Viper Energy — Horizontal Wells Turned to Production in Period (Gross)4		691	655	2,085	739	302	442	381	330	375	375	246
Diamondback-Operated Wells Turned to Production on Viper Acreage (Gross)		146	114	415	124	76	108	88	81	48	68	48
Third-Party-Operated Wells Turned to Production on Viper Acreage (Gross)		545	541	1,670	615	226	334	293	249	327	307	198
Wells Turned to Production — Net 100% Royalty Interest (Total)2		20	15	42	15	7	8	8	7	6	7	3
Diamondback-Operated Wells Turned — Net 100% Royalty Interest		10	9	21	7	4	4	6	4	3	4	2
Third-Party-Operated Wells Turned — Net 100% Royalty Interest		10	7	21	8	2	4	3	3	4	3	1
Wells Turned to Production — Average % Net Royalty Interest (Total)(%)		2.9%	2.3%	2.0%	2.1%	2.2%	1.8%	2.1%	2.1%	1.6%	1.9%	1.2%
Viper Energy — Active Development Well Count / Work-in-Progress (Gross WIPs)4		1,798	1,370	1,388	1,947	1,101	921	867	803	736	760	787
Diamondback-Operated Active Development WIPs on Viper Acreage (Gross)		333	272	263	286	284	239	146	179	132	112	114
Third-Party-Operated Active Development WIPs on Viper Acreage (Gross)		1,465	1,098	1,125	1,661	817	682	721	624	604	648	673
Active Development WIPs — Net 100% Royalty Interest (Total)2		39	37	38	39	30	23	14	18	14	14	13
Diamondback-Operated WIPs — Net 100% Royalty Interest		22	20	21	19	16	13	6	10	8	6	5
Third-Party-Operated WIPs — Net 100% Royalty Interest		17	17	17	20	14	10	8	7	7	8	8
Active Development WIPs — Average % Net Royalty Interest (Total)(%)		2.2%	2.7%	2.8%	2.0%	2.7%	2.5%	1.6%	2.2%	1.9%	1.8%	1.7%
Viper Energy — Total Cash Operating Expense ($/BOE)($)6		4.17	3.92	3.16	3.50	3.60	4.26	3.85	4.16	4.36	4.51	4.03
Viper — Production & Ad Valorem Taxes ($/BOE)($)		3.52	2.98	2.35	2.70	2.91	3.29	3.13	3.33	3.52	3.43	3.13
Viper — Cash General & Administrative ($/BOE)($)		0.65	0.94	0.81	0.80	0.69	0.97	0.72	0.83	0.84	1.08	0.90
Viper — Depletion / DD&A Expense ($/BOE)($)		15.95	17.51	18.98	18.17	17.19	12.97	12.51	12.01	11.19	11.18	11.12
Viper — Net Interest Expense ($/BOE)($)		1.96	2.30	2.92	3.20	2.08	2.52	3.70	3.69	4.32	4.67	3.91
Viper — Oil Realized Price, Hedged ($/Bbl)($)		96.42	72.31	57.28	63.76	62.85	70.26	69	74.27	80.24	75.64	76.56
Viper — Natural Gas Realized Price, Hedged ($/Mcf)($)		1.48	2.27	1.53	1.77	1.58	3.74	1.05	0.56	0.64	1.12	1.34
Viper Energy — Royalty Income ($M)($M)6		658	496	422	393	287	244	225	209	215	205	202
Viper — Total Operating Income ($M)($M)		677	511	435	418	297	245	229	211	216	205	205
Viper — Consolidated Adjusted EBITDA ($M)($M)		642	485	403	393	274	232	208	191	199	184	187
Viper — Cash Available for Distribution to Class A Shares / Units ($M)($M)		262	204	145	165	97	100	88,962	75,448	78,422	72,127	63,751
Viper — Cash Available for Distribution per Class A Share ($/sh)($)		1.37	1.05	0.85	0.97	0.74	0.76	0.86	0.73	0.86	0.79	0.74
Viper — Base Dividend per Share ($/sh)($)		0.38	0.38	0.38	0.33	0.33	0.30	0.30	0.30	0.30	0.27	0.27
Viper — Variable Dividend per Share ($/sh)($)		0.29	0.30	0.14	0.25

WTI Cushing Crude Oil Spot Price ($/Bbl — Monthly & EOQ)($)	97.31	84.81	91.38	57.97	63.96	68.17	68.24	70.12	70.24	79.77	81.28	71.90
Brent Europe Crude Oil Spot Price ($/Bbl — Monthly & EOQ)($)	114	85.40	103	62.54	67.99	71.44	72.73	73.86	74.02	82.25	85.41	77.63
Henry Hub Natural Gas Spot Price ($/MMBtu — Monthly & EOQ)($)	2.95	3.15	3.04	4.26	2.97	3.02	4.12	3.01	2.28	2.54	1.49	2.52
US Oil & Gas Extraction Industrial Production Index (Fed)(×)	154.01	152.90	149.97	149.60	151.74	150.06	146.83	145.96	143.74	145.53	143.11	143.67
US Oil & Gas Extraction Capacity Utilization (% — Fed)(%)	94.9%	95.1%	94.0%	94.5%	96.6%	96.2%	94.7%	94.8%	94.0%	96.0%	95.2%	96.6%
US Drilling Oil & Gas Wells Activity Index (Fed)(×)	105.50	100.90	97.60	100.10	98.40	99.10	103.50	104.50	108.10	108.30	111.30	110.80
US Refined Petroleum Products Producer Price Index (BLS)(×)	458.80	366.60	311.50	217.80	248.80	240.70	241.80	235.60	245.00	266.50	293.90	256.00
US Regular Conventional Gasoline Retail Price ($/Gal — EIA)($)	4.36	4.05	3.64	2.89	3.17	3.15	3.10	3.02	3.21	3.46	3.43	3.13
US No. 2 Diesel Retail Price ($/Gal — EIA)($)	6.29	5.02	4.92	3.62	3.75	3.60	3.58	3.49	3.56	3.72	4.02	3.97

Aggregate Revenues from Contracts with Customers ($M — DB)($M)5		5,546	4,223	3,368	3,914	3,666	4,046	3,704	2,642	2,481	2,225	2,223
Total Oil, Natural Gas & NGL Production Revenue ($M — DB)($M)		4,786	3,825	3,033	3,447	3,316	3,657	3,471	2,354	2,174	2,101	2,165
Crude Oil Production Sales ($M — DB)($M)		4,627	3,445	2,736	2,994	2,852	3,039	3,042	2,160	1,998	1,867	1,920
Natural Gas Liquids Production Sales ($M — DB)($M)		435	359	293	366	367	406	378	211	171	184	180
Natural Gas Production Sales ($M — DB)($M)		-276	21	4	87	97	212	51	-17	5	50	65
Sales of Purchased Oil ($M — DB)($M)		739	385	308	459	335	374	225	282	300	116	52
Consolidated Total Revenue ($M — DB)($M)6		5,562	4,240	3,376	3,924	3,678	4,048	3,711	2,645	2,483	2,227	2,228
Operating Income ($M — DB)($M)		2,512	116	-2,782	1,236	1,139	1,673	1,412	710	1,156	1,118	1,205
Income Before Income Taxes ($M — DB)($M)		2,635	176	-2,333	1,370	943	1,894	1,405	918	1,146	1,032	1,275
Income Tax Provision / (Benefit) ($M — DB)($M)		580	32	-567	287	204	403	115	210	252	223	264
Consolidated Net Income ($M — DB)($M)		1,882	25	-1,458	1,018	699	1,405	1,074	659	837	768	960
Net Income Attributable to Common Stockholders ($M — DB)($M)		1,871	22	-1,452	1,014	695	1,399	1,070	653	831	763	955
Net Income Attributable to Noncontrolling Interest ($M — DB)($M)		173	119	-308	65	40	86	216	49	57	41	51
Net Cash Provided by Operating Activities ($M — DB)($M)4		3,589	1,828	2,343	2,383	1,677	2,355	2,341	1,209	1,529	1,334	1,624
Depreciation, Depletion, Amortization & Accretion ($M — DB)($M)		1,272	1,293	1,389	1,286	1,266	1,097	1,156	742	483	469	469
Net Cash Used in Investing Activities ($M — DB)($M)		-1,395	-658	-118	-2,059	-3,979	-1,653	-1,855	-8,166	-449	-751	-1,464
Net Cash Used in Financing Activities ($M — DB)($M)		-1,906	-1,100	-2,671	7	482	1,175	-695	419	4,932	-269	-405
Dividends Paid to Stockholders ($M — DB)($M)		310	295	286	289	291	290	262	416	352	548	603
Total Assets ($M — DB)($M)4		70,218	70,080	71,059	76,213	71,941	70,066	67,292	65,747	35,637	29,690	29,001
Net Oil & Natural Gas Properties / PP&E ($M — DB)($M)		66,772	66,613	68,621	72,533	69,229	64,896	64,472	63,053	27,099	27,024	26,674
Cash and Cash Equivalents ($M — DB)($M)		462	174	104	159	221	2,041	164	373	6,911	899	585
Total Stockholders' and Noncontrolling Equity ($M — DB)($M)		43,985	42,640	42,967	45,634	42,819	41,743	39,862	38,819	18,527	18,019	17,430
Common Shares Outstanding at Period-End (M — DB)(M)		281	281	285	287	291	287	291	293	178	178	179

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

Primary Key (Core Tier): Hydrocarbon Production (BOE/d & MBOE by Oil, Natural Gas, and NGLs) and Operated Horizontal Wells Drilled & Completed (Gross & Net) disaggregated across the Midland Basin, Delaware Basin, and 12 geological target zones.
Q4 Split Derivations (Step 4 Type 1): Note 3 Disaggregated Commodity Revenue by Basin and MD&A Production vs. Ad Valorem Taxes ($M) derive Q4 via Q4 = Full Year (10-K) − First Nine Months (Q3 10-Q).
Consolidated − Standalone Evaluation (Step 4 Type 2): Diamondback Energy, Inc. does not file parent-only Schedule I financial statements, and its publicly traded consolidated mineral & royalty subsidiary Viper Energy, Inc. (NASDAQ: VNOM, CIK 0002074176 / 0001602065) self-reports full SEC 10-K, 10-Q, and 8-K operational and financial results (Group 8), while Diamondback's 8-K Ex 99.1 directly reports Standalone vs. Viper debt and Consolidated vs. Attributable Adjusted EBITDA (Group 6). Therefore, synthetic consolidated − standalone subtraction is unnecessary.
Early Q3 2026 Actuals: Form 8-K (Item 2.02) filed on 2026-10-08 provides actual Q3 2026 unhedged & hedged realized prices and derivative settlements prior to the full Q3 2026 10-Q.

Data updated 2026-10-29.

Every KPI on its own page

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

Diamondback Energy, Inc. (FANG) operating KPIs

KPIs

Every KPI on its own page

1. Hydrocarbon Production by Commodity & Basin (Primary Key)

2. Drilling & Completion Activity (by Basin & Zone), Lateral Length, Wells & Acreage

3. Disaggregated Revenue by Basin & Commodity (ASC 606 Note 3)

4. Realized Commodity Prices (Unhedged & Hedged through Q3 2026) & Unit Costs ($/BOE)

5. Proved Reserves, PUD Rollforward, Reserve Replacement, F&D Costs & ASC 932 SMOG

6. Cash CapEx Breakdown, Free Cash Flow, Adjusted EBITDA, Standalone vs. Viper Debt & Share Repurchases

7. Management Operational & Capital Guidance (Diamondback Energy & Viper Energy)

8. Subsidiary Viper Energy, Inc. (NASDAQ: VNOM) — Self-Reported Operations & Financials

9. Executive STI Scorecard (ROACE), ESG & Safety, Workforce, Commitments & Form SD

10. External Energy & Oilfield Industry Macro Benchmarks (EIA / FRED / BLS)

11. Financial & Product Revenue Context (from PostgreSQL DB)