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Modernisation plans

The pattern of the Russian refining investments over 2012-2018 is mainly determined by the agreement between 12 Russian oil companies and FAS, Rostechnadzor and Rosstandard over the improvement of refining quality signed in 2011, which also prepared for the introduction of Euro-5 fuel specification standards in July 2016. In particular, during 2013-2018, the oil companies expanded their secondary capacities by adding two coking, twelve hydrotreating, four hydrocracking, three catalytic reforming, two alkylation, two MTBE, six isomerisation and two catalytic cracking units. Following these capacity upgrades, the average NCI reached 6.2 in 2018 (vs 5.3 in 2013), the light products yield reached 61.6% (vs 51.4% in 2013) and all of the refineries became Euro-5 compliant.

While the majority of the planned upgrade work has been completed, we expect the modernisation process will continue, primarily due to a catch-up by some of Rosneft’s delayed projects (mainly conversion units), phase-II modernisation of Gazprom Neft refineries, a delayed coking unit at LUKOIL’s NORSI refinery, construction of the new hydrocracker at NOVATEK’s Ust-Luga complex and Tatneft’s continuing expansion of its

TANECO refinery.

We have collected data on refinery upgrades planned by individual Russian VICs for the next few years (Figures 74-75). The modernisation pipeline is more modest, compared with recent years, in our view, which suggests that refining expenditure is likely to remain under control but still elevated, with 42 new hydrocracking, hydrotreating, catalytic cracking, catalytic reforming, delayed coking, visbreaking, isomerisation and alkylation units scheduled to come on stream (Figure 74), not accounting for the independent refineries.

We estimate Russia’s average NCI will increase to around 7.1 in 2021 (from 6.2 in 2018) as a result of the anticipated changes, although some of these advertised projects may be delayed or cancelled.

Renaissance Capital

20 June 2019

Russian oil & gas

Significant complexity upgrades during 2013-2018

Current modernisation pipeline is more modest, dominated by Rosneft and Tatneft

Figure 74: Refinery modernisation plans by company (new units and primary capacity additions)

		Primary					Number of new units to be constructed
	Company					Catalytic		Hydro-	Hydro-
		capacity (mnt)	Vacuum	Coking	Thermal		Reforming			Isomerisation	Alkylation	Hydrogen	Sulfur	MTBE
						cracking		cracking	treating
	Rosneft		1	2		1	1	6	8	1	2			2
	LUKOIL			1						1
	Gazprom Neft			1			1	2	2			1	1
	Surgutneftegas
	Bashneft			1							1
	Slavneft			1				1
	TAIF							1
	NNK	5
	Tatneft	6	1			1		2	3		1	1		1
	NOVATEK							1				1
	Independent	17	4	3	1	1	4	3	5	4	0	2	3	0
	Total Russia	28	6	9	1	3	6	16	18	6	4	5	4	3

Source: Company data, Renaissance Capital

Rosneft has the most extensive refining modernisation programme in Russia, which includes the construction of eight hydrotreatment units, one catalytic cracking, one reforming, six hydrocracking (including one hydroconversion unit), two alkylation and two coking units at its refineries. However, Rosneft’s management has previously indicated that the modernisation will be focused on the projects already in construction, including hydrocracking units at Novo-Kuibyshev, Tuapse, Achinsk and Komsomolsk refineries, delayed coking unit at Achinsk refinery and renovation of the coking unit at NovoKuibyshev, which we associate with the push to increase the conversion capacities in preparation for the IMO 2020 regulation. We note that this trend mostly persists for the most of the other future refining modernisation projects, that have also shifted their focus from the construction of treatment to conversion capacities and renovation of existing units.

Bashneft, with one of the most complex refining portfolios in Russia, had less incentive to modernise its secondary capacities than other oil & gas companies, and we envisage little

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new investment bar the possible construction of a delayed coking unit in Ufa. Having completed the renovation of the hydrocracking unit which increased its capacity by 0.6mn tpa in Ufanertekhim, construction of hydrotreating unit (1.3mn tpa) in Ufa and new construction of the 0.153mn tpa of hydrogen and 0.448mn tpa of the alkylation capacities at the Novoil refinery, Bashneft refineries reached an NCI of 9.9 in 2018, with the light products yield standing at 63% last year. We estimate that the actual NCI stands lower at 9.5 in 2018, as the hydrocracker unit at Ufaneftekhim has remained non-operational since being damaged in 2016. After taking over Bashneft in 2016, Rosneft carried on with its plans to construct a new delayed coking unit of 2mn tpa at Ufa refinery and reconstruct the hydrocracker unit at Ufaneftekhim.

Gazprom Neft is continuing with its Phase-II modernisation programme, which includes the launch of the ‘Euro+’ units at its Moscow refinery, replacing the outdated distillation, reforming and hydrotreating units with the new ones, in 2019 and the construction of the Deep Oil Refining complex in 2022. Omsk refinery is scheduling to complete the renovation of the primary and secondary capacities in 2019-2020, followed by the construction of the two conversion units – Deep Oil Refining Complex and delayed coking units.

LUKOIL completed its modernisation programme in 2016, having increased its NCI from 6.8 in 2013 to 7.4 in 2018 and a substantially higher light products yield of 69% (vs 53% in 2013). The Norsi refinery saw a 35% expansion of vacuum distillation capacity. Regarding the expansion of secondary capacities, LUKOIL constructed a second catalytic cracker (2mn tpa), a gasoline hydrotreater (1.1mn tpa) and an alkylation unit (0.3mn tpa) at Norsi. At the Volgograd refinery, LUKOIL expanded primary distillation capacity to 15.7mn tpa, allowing it to cover the increase in demand for throughput by the newly constructed VGO conversion plant. LUKOIL also renovated the hydrotreatment units at its Perm and Ukhta refineries. In addition, the heavy residuals complex was constructed at the Perm refinery, including a 2.1mn tpa coking unit and 1.5mn tpa hydrotreating units. In terms of remaining projects, LUKOIL schedules to construct an alkylation unit at Norsi in 2020 and a delayed coking unit in 2021, which would increase the NCI up to 7.8.

Surgutneftegas has made no significant changes to its secondary capacity since 2013, when it launched a new hydrotreating unit and a Deep Refining Complex. In 2018, the company has launched a new LK-2B high-octane gasoline production complex, including hydrotreating (2.3mn tpa), isomerisation unit (1.1mn tpa) and reforming (1.2mn tpa).

The YaNOS refinery saw the construction of a diesel hydrotreating unit and modernised alkylation unit which allowed it to increase its capacity by 0.12mn tpa. The modernisation programme resulted in YaNOS’s NCI increasing to 7.8 by 2017 (from 6.7 in 2013). In 2017 Slavneft completed the Group-III quality base oils production of 0.1mn tpa. The long-term modernization program of Slavneft schedules the construction of the sulfuric acid unit (0.045mn tpa) and Residue Conversion Complex based around the delayed coking unit in 2024.

TAIF finished the construction of the deep refining complex at its Nizhnekams refinery with a hydrocracking capacity of 3.7mn tpa in 2016-2017 but only recently received legal approval for the operations and plans a commercial launch in 2019. The complex’s capacities will be used to convert VGOs and other heavy oil residuals into light products.

Through 2015-2018, Tatneft launched delayed coking (2mn tpa), hydrocracker (2.9mn tpa), naphtha (1.1mn tpa), diesel (1.6mn tpa) and kerosene (0.5mn tpa) hydrotreating, isomerization (0.42mn tpa) and reforming (0.714mnt tpa) units at TANECO refinery, with the latter five being launched in 2018, which allowed the company to launch the gasoline production line in February 2019.

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Tatneft continues with the modernisation of the TANECO refinery. The company plans to launch the reforming unit, which will allow it to commence production of Euro-5 gasolines from its gasoline production line, in 2019, as well as to finish mechanical completion of the new AVCDU-6 and vacuum block of the visbreaker unit, as well as to construct the sulfolane production line and heavy gasoil (HGO) hydrotreatment unit. Subsequent additions to secondary capacity include pilot hydroconversion units in 2019-2020 and a catalytic cracker in 2020. Post 2020, Tatneft plans to add an aromatics production complex, a middle distillate and a naphtha hydrotreating units, alkylation, hydrogen and MTBE units, a VGO hydrocracker and a full-scale hydroconversion unit. Following the modernisation, the company expects TANECO to almost double its current capacity to 15.3mn tpa, while maintaining the current quality of its refining parameters, with the targeted light product yield at 89% and the conversion rate at 99%.

NOVATEK is scheduled to construct and launch a hydrocracking unit (1mn tpa) in 2020, which would eliminate fuel oil output at its Ust-Luga Complex.

NNK has undertaken an extensive modernisation programme at its Khabarovsk refinery, increasing primary capacity by 2.5mn tpa to 5mn tpa and constructing a new visbreaking unit (0.75mn tpa), a hydrocracker (0.5mn tpa) and a gasoil hydrotreater (1.2mn tpa).

Modernisation has resulted in an increase in the light products yield from 29.6% in 2013 to 65.5% in 2018, with a current NCI of 4.9 (2.5 in 2013). We summarise the ongoing modernisation projects in Figure 75.

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Figure 75: Russian refineries – major upgrade projects

Company	Recent activities (2013-2018)	Further modernisation plans
Rosneft

Angarsk

Syzran

Kuibyshev

Komsomolsk

Novo-Kuibyshev

Achinsk

Tuapse

Ryazan

Saratov

Nizhevartovsk

Constructed an isomerisation unit in 2010. Renovated the catalytic reformer unit in 2011, launched an MTBE unit (0.128mn tpa) in 2015.

Renovated the catalytic reformer unit (0.6mn tpa) and constructed an isomerisation unit in 2011.

Isomerisation unit (0.28mn tpa) was launched in 2014. The 1.15mn tpa catalytic cracking unit and MTBE facilities (0.04mn tpa) were finished in 2016.

Reconstruction of the catalytic reforming unit.

Renovation of the catalytic reformer unit in 2011-2012 and launch of the delayed coking unit in 2011.

Launched reforming (1.2mn tpa) and isomerisation capacities (0.28mn tpa) in 2015. Reconstruction of the isomerisation unit.

Reconstruction works on the gasification unit to repair the damage from technological explosion. Renovation of the hydrotreating unit in 2011.

Replaced the distillation capacities with a new unit in 2013, including a naphtha hydrotreating section.

Isomerisation unit of 0.8mn tpa built in 2014. Reconstruction of the hydrotreatment unit (2mn tpa). Vacuum distillation block installed in 2015.

Reconstruction of visbreaking unit after a fire. Reconstruction of the 2.2mn tpa gasoil hydrotreatment units in two phases. Isomerisation unit (0.3mn tpa) launched in 2013. The primary distillation capacity renovated and increased. na

Construction of gasoline (0.5mn tpa) and gasoil (4mn tpa) hydrotreatment and alkylation (0.13mn tpa) units.

Construction of catalytic cracking (1.1mn tpa), hydrotreatment (2.5mn tpa), MTBE (0.04mn tpa) and alkylation (0.158mn tpa) units.

Hydrotreating and alkylation units are planned for construction.

New hydrocracker (2mn tpa) and gasoil hydrotreatment (1.6mn tpa) units.

Construction of a hydrocracking unit (2mn tpa) and gasoil hydrotreatment unit (2.75mn tpa). Reconstruction of the delayed coking unit to increase capacity up to 1.5mnt pa. A new atmospheric-vacuum distillation unit (2mn tpa) is planned.

New delayed coking (3mn tpa) and hydrocracking-hydrotreating (3.6mn tpa) units, as well as construction of the vacuum block.

Construction of flexi-coking (2.8mn tpa), hydrocracking (4mn tpa), hydrotreating (4.23mn tpa), reforming (1.5mn tpa) and isomerisation (0.8mn tpa) units in 2017-2020.

Construction of hydrocracker (2.2mn tpa) in 2023. MTBE unit is scheduled. Studies the feasibility of constructing a new atmospheric-vacuum distillation unit (5mn tpa).

Construction of hydroconversion unit in 2024. Expansion of main vacuum and visbreaking capacities as well as reconstruction of the bitumen unit are scheduled up to 2023.

na

LUKOIL

Norsi

Perm

Volgograd

Ukhta

Expansion of the total vacuum distillation capacity. The construction of the second	The construction of isomerisation unit (0.44mn tpa) scheduled for 2020.
catalytic cracker (2mn tpa), gasoline hydrotreater (1.1mn tpa) and alkylation unit	Delayed coking unit (2.1mn tpa) is scheduled for 2021. New gasoline
(0.3mn tpa) in 2015.	production units are planned.
The renovation of the diesel hydrotreating unit (1.8mn tpa). The delayed coking
unit capacity expanded up to 1mn tpa. The construction of the Heavy residuals	Modernisation of AV distillation units. Modernisation of the refinery’s control
refining plant was finished in 2015, including the delayed coking unit of 2.1mn tpa	systems.
and hydrotreatment unit of 1.5mn tpa.
The refining capacity was expanded with the introduction of the new 6mn tpa
distillation unit up to 15.7mn tpa. In 2016, the VGO conversion plant constructed,	A three new units are planned for the refinery to be launched in 2020-2021.
including the hydrocracking unit of 3.5mn tpa.
Reconstruction of the hydrotreatment (2mn tpa) was completed.	na

Surgutneftegas

	The construction of hydrotreating unit (2mn tpa) in 2012-2013 and the Deep
	Refining Complex. Reconstruction of the hydrotreatment capacities in 2015-2016.
Kirishi	In 2018 launched the LK-2B high-octane gasoline production complex, including	na
	isomerization (1.1mn tpa) and reforming (1.2mn tpa) units and hydrotreatment
	block (2.3mn tpa).

Bashneft

Ufaneftekhim	Upgrade of the hydrocracking unit (capacity increased by 0.6mn tpa).
Ufa	Construction of a hydrotreating unit of 1.3mn tpa in 2014.

Construction of a hydro-aromatisation unit and new sulphur capacities. Reconstruction of distillation and replacement of hydrocracker units.

Reconstruction of the aromatics complex.

Construction of the delayed coking unit (2mn tpa) and new sulphur capacities. Reconstruction of the distillation units.

	Novo-Ufa	Construction of alkylation (0.448mn tpa) and hydrogen production (0.153mn tpa)	Reconstruction of the distillation units. The expansion of the hydrocracker unit
		units.	was cancelled.

Gazprom Neft

Omsk

Moscow

		Replace part of the primary distillation capacity with 8.4mn tpa of crude and
	Reconstruction of the primary distillation capacities and catalytic cracking units.	1.2mn tpa condensate in 2019. Construction of the delayed coker (2mn tpa)
		Deep Oil Refining Complex including hydrocracker (2mn tpa), and diesel
	Hydrogen production unit launched in 2018.
		hydrotreatment unit (2.5mn tpa) in 2020. Renovation of the reforming units to
		increase the high-octane gasoline production by 50% in 2020.
	Construction of additional isomerization (0.65mn tpa) and gasoline hydrotreatment	Construction of "Euro+" refining complex including a 6mn tpa of AV-distillation,
	(1.2mn tpa) units. Reconstruction of the gasoil hydrotreatment unit (2mn tpa) and	1mn tpa of catalytic reforming and 2mn tpa of diesel hydrotreating capacity.
		Reconstruction of the primary distillation capacities. Construction of the Deep
	the catalytic cracker (capacity up to 2.4mn tpa).	Oil Refining Complex in 2022.

Slavneft

		Construction of a diesel hydrotreating unit (1.6mn tpa), modernisation of the	Construction of the sulfuric acid unit (0.045mn tpa) in 2019 and construction of
	YaroslavNOS	alkylation unit. Reconstruction of the catalytic cracking and MTBE units.
			the Deep Refining Complex, including a delayed coker unit in 2024.
		Installation of the Group-III quality base oils production unit of 0.1mn tpa.
	TAIF
	Nizhnekamsk	Reconstruction of the hydrotreating unit.	Mechanical completion of the Heavy Residue Conversion Complex (3.7mn
			tpa), including hydrocracking section, in 2018 and commercial launch in 2019.

Source: Company data, Renaissance Capital

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Figure 75: Russian refineries – major upgrade projects (continued)
Tatneft
		Expansion of the primary distillation capacity by 6mn tpa. Addition of the
	Construction of the delayed coking unit (2mn tpa), hydrocracker (2.9mn tpa),	vacuum block to the visbreaking unit and construction of heavy gasoil
	hydrogen (0.1mn tpa) and high-index oils (0.25mn tpa) units. Isomerization	hydrotreater (0.85mn tpa), sulfolane production line in 2019, catalytic cracker
TANECO	(0.42mn tpa) and naphtha hydrotreating (1.1mn tpa) units launched in January	(1.1mn tpa) in 2020, middle distillates HDT (3.7mn tpa) and naphtha HDT,
	2018, followed by diesel (1.6mn tpa) and kerosene (0.5mn tpa) HDTs in July	aromatics production line (0.714mn tpa), alkylation, hydrogen and MTBE units
	2018 and catalytic reforming unit (0.714mn tpa) in November 2018. Upgrade of	in 2021-2022. A new hydrocracking unit is scheduled for 2026 (1.2mn tpa). A
	the primary distillation capacities in 2013.	test hydroconversion unit is scheduled for the pilot run (0.1mn tpa) in 2019, to
		be constructed in the full-scale (2mn tpa) in 2026.
NNK
	Upgrade of the primary distillation unit up to 5mn tpa of annual capacity.
Khabarovsk	Construction of the visbreaking unit (0.75mn tpa), hydrocracker (0.5mn tpa) and	Considers expansion of the primary distillation capacity by 5mn tpa.
	gasoil hydrotreater (1.2mn tpa). Reconstruction of catalytic reformer unit in 2013.
NOVATEK
	The launch of the Ust-Luga Complex, including of 3mn tpa two stable gas	The new hydrocraker unit (1mn tpa), including a hydrogen capacity, is
Ust-Luga	condensate fractionation trains, in 2013. The complex reached the utilisation level
		scheduled for launch in 2020.
	of 117% of the nameplate capacity in 2015.

Source: Company data, Renaissance Capital

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Figure 76: Russia’s refining facilities in detail, 2018

			(ktCrudepa)	Crude processing		Coking	Cracking		hydroCat.- cracking	Alkylation	Combination		isation-Isomer	Treating
Company	Refinery/	NCI		(b/d)Crude	Vacuum distillation		Thermal operations	crackingCat.			Pol. /Dim.	Cat. reforming		hydroCat. treating	Aromatics
	company
Bashneft		9.89	23,500	470,000	254,471	46,058	78,321	80,329	27,000	13,817	979	60,206	27,713	277,489	8,234
	Novoil (Novo-Ufa)	11.89	7,400	148,000	93,800	14,058	30,123	0	0	13,817	0	40,164	10,041	113,123	0
	Ufa	8.00	6,600	132,000	98,671	0	24,099	44,181	0	0	979	11,808	7,631	105,927	0
	Ufaneftekhim	9.63	9,500	190,000	62,000	32,000	24,099	36,148	27000	0	0	8,234	10,041	58,439	8,234
Gazprom		4.06	17,310	346,191	146,598	0	9,397	12,853	30,123	1,174	0	20,082	8,680	93,025	1,591
	Salavat	6.30	10,000	200,000	146,598	0	9,397	12,853	30,123	1,174	0	20,082	8,680	93,025	1,591
	Surgut CSP		4,000	79,996	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.
	Astrakhan'		3,310	66,195	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.
	Gazprom other		n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.
Gazprom Neft		7.22	34,989	699,771	412,442	41,820	76,653	125,765	0	5,000	4	63,540	29,000	369,789	11,139
	Omsk	7.45	22,229	444,571	228,937	41,820	56,571	77,765	0	5,000	0	32,132	16,000	202,419	11,139
	Moscow	6.80	12,760	255,200	183,505	0	20,082	48,000	0	0	4	31,409	13,000	167,370	0
LUKOIL		7.36	50,150	1,003,000	450,604	80,000	56,300	89,300	132,200	17,000	0	136,900	37,500	503,900	2,200
	Perm	9.70	13,100	262,000	116,300	56,000	0	9,300	65,200	0	0	36,900	13,000	131,000	2,200
	Volgograd	6.59	15,650	313,000	108,000	24,000	0	0	67,000	0	0	43,700	9,900	96,000	0
	Ukhta	4.80	4,000	80,000	40,300	0	14,100	0	0	0	0	9,200	4,300	33,900	0
	NORSI	6.98	17,000	340,000	178,000	0	42,200	80,000	0	17,000	0	47,100	10,300	243,000	0
	LUKOIL - other	3.00	400	8,000	8,004	0	0	0	0	0	0	0	0	0	0
NNK		4.89	5,000	100,000	57,600	0	15,000	0	10,120	0	0	9,000	2,400	40,862	0
	Khabarovsk	4.89	5,000	100,000	57,600	0	15,000	0	10,120	0	0	9,000	2,400	40,862	0
Rosneft*		6.61	112,035	2,246,202	1,034,478	90,799	176,074	260,193	57,123	24,177	1,729	275,137	94,108	1,009,580	38,968
	Komsomolsk	4.41	8,300	166,000	137,161	20,000	11,300	0	0	0	0	12,000	2,008	25,066	0
	Tuapse	2.84	12,000	240,000	110,452	0	0	0	0	0	0	0	0	110,452	0
	Novokuibyshev	8.36	7,950	159,000	73,000	11,889	0	14,258	0	0	0	44,984	10,400	77,896	6,025
	Kuibyshev	7.76	7,000	140,000	40,700	0	20,082	41,008	14,058	800	750	26,107	5,600	79,904	6,000
	Syzran'	5.58	8,500	170,000	48,800	0	24,299	12,933	16,066	0	0	23,496	5,600	99,384	1,760
	Angarsk	7.05	10,185	203,700	81,054	12,853	0	42,514	0	2,560	0	20,082	5,600	52,113	4,900
	Achinsk	3.90	7,500	150,000	40,184	0	0	0	0	0	0	23,095	7,129	59,343	0
	Ryazan'	7.43	17,807	356,140	163,636	0	21,990	69,151	0	7,000	0	42,173	24,033	159,653	12,049
	Saratov	4.82	7,000	140,002	65,780	0	20,082	0	0	0	0	22,994	6,025	68,279	0
	Nizhnevartovsk	1.00	2,000	40,000	0	0	0	0	0	0	0	0	0	0	0
	Rosneft - other	2.68	965	19,301	16,240	0	0	0	0	0	0	0	0	0	0
Slavneft		7.8	15,000	300,000	100,411	0	0	30,123	42,976	4,057	0	33,818	29,542	102,710	6,587
	Yaroslavl'	7.8	15,000	300,000	100,411	0	0	30,123	42,976	4,057	0	33,818	29,542	102,710	6,587

Note: Primary and secondary capacity is based on Oil & Gas Journal data adjusted to reflect InfoTEK and company data where available. A number of mini-refineries excluded from total figures. Rosneft’s NCI is calculated on consolidated basis. All figures are in barrels per day (b/d), unless otherwise stated.

Renaissance Capital

20 June 2019

Russian oil & gas

Products

Oxygen-ates	Lubes	Hydrogen	Coke	Sulphur	Asphalt
0	16,126	25	260	432	14,275
0	8,796	16	260	360	8,796
0	0	2	0	72	498
0	7,330	6	0	0	4,981
3,000	0	0	0	290	0
3,000	0	0	0	290	0
n.a.	n.a.	n.a.	n.a.	n.a.	n.a.
n.a.	n.a.	n.a.	n.a.	n.a.	n.a.
n.a.	n.a.	n.a.	n.a.	n.a.	n.a.
4,750	8,403	50	510	200	32,070
3,750	7,600	28	510	200	15,000
1,000	803	22	0	0	17,070
0	16,400	208.6	1,522	880	49,492
0	9,400	56.5	490	316	17,592
0	7,000	110.1	1,020	177	4,800
0	0	0	12	11	4,300
0	0	42	0	376	22,800
0	0	0	0	0	0
0	0	2	0	37	5,811
0	0	2	0	37	5,811
0	31,092	55	1,700	1,098	61,863
0	0	0	0	38	0
0	0	0	0	0	0
0	3,705	2	1,030	0	12,286
0	0	0	0	0	0
0	0	0	0	288	9,037
0	5,638	23.7216	410	0	8,500
0	0	0	0	17	9,037
0	5,623	0	0	274	4,860
0	0	4	0	50	3,868
0	0	0	0	0	0
0	0	0	0	0	0
800	7,029	20	0	0	10,041
800	7,029	20	0	0	10,041

Source: Company data, Oil & Gas Journal, Renaissance Capital

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	Figure 76: Russia’s refining facilities in detail, 2018 (continued)
				Crude processing				Cracking				Combination			Treating					Products
	Company	Refinery/	NCI	(ktCrudepa)	(b/d)Crude	Vacuum distillation	Coking	Thermal operations	crackingCat.	hydroCat.- cracking	Alkylation	Pol. /Dim.	reformingCat.	isation-Isomer	hydroCat. treating	Aromatics	ates-Oxygen		Lubes	Hydrogen	Coke	Sulphur	Asphalt
		Company
	Surgutneftegas		6.56	20,100	402,000	184,527	0	38,598	0	58,000	0	0	68,181	32,041	227,066	7,029	0		0	12	0	150	20,082
		Kirishi	6.55	20,100	402,000	182,527	0	38,598	0	58,000	0	0	68,181	32,041	227,066	7,029	0		0	12	0	150	20,082
		SurgutNG-Other		n.a.	n.a.	2,000	0	0	0	0	0	0	0	0	0	0	0		0	0	0	0	0
	TAIF		6.45	8,350	166,999	56,230	0	36,148	18,676	74,000	3,069	0	0	0	50,607	0	625		0	18	0	98	2,812
		Nizhnekamsk	6.45	8,350	166,999	56,230	0	36,148	18,676	74,000	3,069	0	0	0	50,607	0	625		0	18	0	98	2,812
	NOVATEK		1.0	7,000	140,000	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.		n.a.	n.a.	n.a.	n.a.	n.a.
		Ust-Luga	1.0.	7,000	140,000	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.		n.a.	n.a.	n.a.	n.a.	n.a.
	Tatneft		9.87	8,700	174,000	95,700	40,000	48,000	0	58,000	0	0	14280	8,400	64,000	0	625		5,000	13	0	102	0
		TANECO	9.87	8,700	174,000	95,700	40,000	48,000	0	58,000	0	0	14,280	8,400	64,000	0	625		5,000	13	0	102	0
		Tatneft - other		300	6,000	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.	n.a.		n.a.	n.a.	n.a.	n.a.	n.a.
	Other
	New Stream	Mariysk	1.59	1,600	32,001	9,520	0	0	0	0	0	0	0	0	0	0	0		0	0	0	0	0
	Dagestan Oil	Makhachkala		-	0	0	na	na	na	na	na	na	na	na	na	na	na		na	na	na	na	na
	Ug-Rusi	Novoshakhtinsk	1.71	5,000	100,004	25,000	0	0	0	0	0	0	0	0	0	0	0		0	0	0	0	14,058
	Oil Technologies	Afipsk	3.86	6,000	120,000	47,000	0	60,000	0	0	0	0	12,000	0	12,000	0	0		0	0	0	0	0
	SOCAR	Antipinsk	4.58	9,040	180,792	72,000	34,000	0	0	0	0	0	6,000	4,800	99,000	0	0		0	3	0	82	0
	Forteinvest	Orsk	6.41	6,600	132,000	47,000	0	24,099	0	32,132	0	0	12,000	6,000	98,025	0	0		0	0	0	329	10,128
	Krasnodareconeft	Krasnodar	2.92	3,000	60,000	14,472	0	10,143	0	0	0	0	0	0	25,000	0	0		0	0	0	0	5,645
	Mendeleyev Group	Yaroslavl'		500	10,000
	Mini refineries			2,170	43,398	na	na	na	na	na	na	na	na	na	na	na	na		na	na	na	na	na
		Tomsk		-	-	na	na	na	na	na	na	na	na	na	na	na	na		na	na	na	na	na
		Ulyanovsk		-	-	na	na	na	na	na	na	na	na	na	na	na	na		na	na	na	na	na
		Yakutsk		-	-	na	na	na	na	na	na	na	na	na	na	na	na		na	na	na	na	na
	TOTAL RUSSIA		6.18	322,561	6,451,212	2,753,583	286,619	550,412	536,910	494,674	54,476	1,733	650,938	252,471	2,695,564	67,513	9,800		67,924	382	3,732	3,266	212,001
	US average 2018		10.20	930,433	18,608,654	8,523,659	2,695,100	25,000	5,463,198	2,234,790	1,172,537	71,510	3,466,333	724,039	16,066,864	316,830	32,250		216,252	3,828	136,437	35,749	639,105
	China average 2018		3.58	519,415	10,388,293	885,823	545,730	0	1,163,324	605,213	50,700	0	598,164	17,742	1,775,639	128,693	900		29,000	306	9,860	5,331	83,235
	World average 2018		6.49	4,593,193	91,863,853	29,719,861	5,451,075	3,185,889	14,797,127	7,018,536	2,140,809	186,950	11,635,797	1,803,401	47,716,335	1,145,003	189,184 770,529 112,654 209,973 114,399 1,966,758

Note: Primary and secondary capacity is based on Oil & Gas Journal data adjusted to reflect InfoTEK and company data where available. A number of mini-refineries excluded from total figures. All figures are in barrels per day (bpd), unless otherwise stated.

Source: Company data, Oil & Gas Journal, InfoTEK, Renaissance Capital

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