copy of global refinery shutdown roundup sample

Hydrocarbon Publishing Co. Copyright protected. 2008 73

Date of last update: December 27, 2010

In the "Shutdown date" and "Restart date" columns, "*-" indicates an unknown month, day, or year. See "Key" sheet for additional notes.*For refineries that have multiple unit shutdowns, an entry was created for each unit.**Regions: (1) United States, (2) Canada, (3) Latin America & Caribbean, (4) Western Europe, (5) Eastern Europe, (6) Middle East, (7) Africa, (8) Asia-Pacific

Shutdown date Restart dateRegion** M D Y M D Y Refiner City Country Refinery process

1 01 01 11 *- *- 11 LA US 440 Fluid Catalytic Cracking

1 11 25 10 12 25 10 Holly Tulsa OK US 125 Fluid Catalytic Cracking

1 09 25 10 12 20 10 TX US 345 Hydrocracking

1 09 25 10 12 20 10 TX US 345 Catalytic Reforming

3 03 01 10 12 23 10 PDVSA 320 Crude Distillation

3 03 01 10 12 23 10 PDVSA 320 Fluid Catalytic Cracking

To start a new search, be certain to un-filter your results by pointing to Filter on the Data menu, and then click Show All. The drop-down buttons will appear in black.

State or province

Refinery capacity, K

b/d

Citgo Petroleum

Lake Charles

ExxonMobil

Beaumont

ExxonMobil

Beaumont

Refineria Isla Curazao

Netherlands Antilles




3 03 01 10 12 23 10 PDVSA 320 Crude Distillation

8 01 *- 11 02 *- 11 India 660 Fluid Catalytic Cracking

8 12 07 10 12 20 10 Kashima Japan 210 Fluid Catalytic Cracking

1 12 04 10 12 18 10 LA US 193

8 12 07 10 12 18 10 Cosmo Oil Yokkaichi Japan 147 Crude Distillation


1 12 07 10 02 *- 11 Benicia CA US 140 Fluid Catalytic Cracking



Reliance Industries

Jamnagar

Kashima Oil

Chalmette Refining

Chalmette

General outage, turnaround, or closure

Valero Energy


1 12 17 10 12 19 10 TX US 250 Sulfur Plant

8 12 20 11 *- *- *- SK Energy Ulsan 817 Hydrotreating

8 12 24 10 12 28 10 Cosmo Oil Yokkaichi Japan 147 Fluid Catalytic Cracking

8 01 *- 11 02 *- 11 India 660 Hydrotreating

7 12 19 10 *- *- *- Naftec Arzew Algeria 060

7 12 22 10 *- *- *- Kaduna Nigeria 110 General Equipment

7 12 22 10 *- *- *- Nigeria 150 General Equipment

1 12 18 10 12 19 10 BP Ferndale WA US 222

Valero Energy

Port Arthur

South Korea

Reliance Industries

Jamnagar


Nigerian National Petroleum


Port Harcourt



1 12 20 10 12 20 10 IL US 306 Fluid Catalytic Cracking

1 12 20 10 12 20 10 Convent LA US 227

1 12 20 10 12 20 10 Torrance CA US 150 Fluid Catalytic Cracking

1 12 20 10 12 20 10 Torrance CA US 150 Alkylation

1 12 23 10 12 *- 10 Joliet IL US 238

1 12 23 10 12 23 10 TX US 070 General Equipment

1 12 23 10 12 23 10 CA US 015

1 12 23 10 12 23 10 Tacoma WA US 039

2 *- *- 10 12 23 10 Sarnia ON Canada 121 General Equipment

ConocoPhillips

Wood River

Motiva Enterprises


ExxonMobil

ExxonMobil

ExxonMobil


Alon USA Energy

Big Spring

San Joaquin Refining

Bakersfield


US Oil & Refining


Imperial Oil



1 03 *- 11 *- *- 11 Robinson IL US 204

8 12 10 10 12 15 10 Negishi Japan 340 Crude Distillation

8 11 17 10 12 25 10 Mumbai India 240 Crude Distillation

8 11 17 10 12 25 10 Mumbai India 240 Fluid Catalytic Cracking

8 05 25 11 06 *- 11 S-Oil Onsan 520 Crude Distillation

8 09 *- 11 10 *- 11 GS Caltex Yosu 680 Crude Distillation

6 10 30 10 12 18 10 Sohar Oman 116

5 12 03 10 12 17 10 Litvinov 101 Hydrocracking

4 12 13 10 12 27 10 Petroplus Germany 110

4 12 16 10 12 22 10 Tamoil Cremona Italy 094

6 10 25 10 12 14 10 Haifa Israel 130 Catalytic Reforming

6 10 25 10 12 14 10 Haifa Israel 130

Valero Energy

Corpus Christi

Marathon Oil


JX Holdings

Bharat Petroleum

Bharat Petroleum

South Korea

South Korea

Oman Refinery


Ceska Rafinerska

Czech Republic

Ingolstadt

H2 Production/Purification/Rec

overy


Oil Refineries Ltd.

Oil Refineries Ltd.


overy


4 01 13 11 02 17 11 France 119

4 *- *- 11 *- *- 11 ERG Priolo Sicily Italy 225

1 12 09 10 12 11 10 Tesoro Martinez CA US 161

1 12 10 10 12 10 10 CA US 139

1 12 11 10 12 11 10 KS US 135

1 12 14 10 12 14 10 Sunoco PA US 175 General Equipment

1 12 14 10 12 14 10 Memphis TN US 180

1 12 15 10 12 15 10 LA US 440

1 12 15 10 12 15 10 TX US 279

1 12 15 10 12 15 10 Houston TX US 268

1 12 08 10 12 14 10 Houston TX US 090 Fluid Catalytic Cracking

1 12 10 10 12 14 10 TX US 070 Utilities Production


1 12 15 10 01 05 11 BP Carson CA US 252

3 *- *- 11 *- *- 11 Acajutla 022

ExxonMobil

Fos-sur-Mer




ConocoPhillips

Wilmington


Frontier Oil

El Dorado


Marcus Hook

Valero Energy


Citgo Petroleum

Lake Charles


Flint Hills Resources

Corpus Christi


LyondellBasell


Valero Energy

Alon USA Energy

Big Spring

Valero Energy

Corpus Christi


ExxonMobil

El Salvador



8 03 *- 11 03 *- 11 Sinopec Jinling Jiangsu China 270 Crude Distillation

8 03 *- 11 03 *- 11 Sinopec Jinling Jiangsu China 270 Coking

4 01 *- 11 *- *- *- Corinth Greece 110 Crude Distillation

1 11 29 10 12 07 10 Memphis TN US 180 Fluid Catalytic Cracking

3 12 02 10 12 07 10 PDVSA Cardon 940

1 12 04 10 12 04 10 Chevron MS US 330 General Equipment

1 12 04 10 12 04 10 TX US 345

1 12 05 10 12 07 10 Lemont IL US 159

1 12 08 10 12 08 10 Lemont IL US 159 Hydrotreating

1 12 05 10 12 05 10 Sweeny TX US 247 General Equipment

1 12 09 10 12 09 10 Sweeny TX US 247

Motor Oil Hellas

Aghii Theodori

Valero Energy

Venezuela


Pascagoula

ExxonMobil

Beaumont


Citgo Petroleum


Citgo Petroleum

ConocoPhillips

ConocoPhillips



1 12 05 10 12 05 10 Houston TX US 268 General Equipment

1 12 06 10 12 06 10 Tesoro WA US 113

1 12 07 10 12 07 10 Chevron CA US 269

1 12 08 10 12 08 10 NJ US 166

1 12 08 10 12 08 10 Westlake LA US 239 General Equipment

3 12 08 10 12 09 10 Ecuador 110

1 12 03 10 12 03 10 Norco LA US 220 Sulfur plant

1 12 07 10 12 07 10 Norco LA US 220 General Equipment

1 09 17 10 12 06 10 BP Whiting IN US 385 Fluid Catalytic Cracking1 12 05 10 12 08 10 Tesoro CA US 100

1 *- *- *- 12 08 10 BP TX US 451 Hydrocracking

1 *- *- *- 12 08 10 BP TX US 451 Hydrotreating

LyondellBasell

Anacortes


El Segundo


Valero Energy

Paulsboro


ConocoPhillips

Petroecuador

Esmeraldas


Motiva Enterprises

Motiva Enterprises

Wilmington


Texas City

Texas City


8 11 *- 10 11 30 10 Cosmo Oil Yokkaichi Japan 147 Crude Distillation

8 02 25 11 *- *- *- Sinopec China 210 Crude Distillation

4 11 10 10 12 01 10 Dundee Scotland UK 012

4 11 29 10 11 29 10 IES Mantova Italy 069 General Equipment

4 11 30 10 11 30 10 Sweden 028

6 02 *- 11 03 *- 11 Al-Jubail 290 Crude Distillation

6 04 25 11 05 31 11 Rabigh 400

1 11 23 10 11 30 10 LA US 247 Fluid Catalytic Cracking

Guangzhou

Guangdong

AB Nynas Petroleum


AB Nynas Petroleum

Nynashamn


Saudi Aramco Shell Refinery

Saudi Arabia

Saudi Aramco

Saudi Arabia


ConocoPhillips

Belle Chasse


1 11 23 10 11 30 10 LA US 247 Alkylation

1 11 24 10 11 30 10 Torrance CA US 150

2 11 26 10 11 26 10 AB Canada 187

1 11 27 10 11 27 10 KS US 114 Sulfur Plant

1 11 27 10 11 27 10 Norco LA US 220

1 11 28 10 11 28 10 Holly Tulsa OK US 125

1 11 28 10 11 28 10 Sweeny TX US 247 Fluid Catalytic Cracking

1 11 29 10 11 29 10 Houston TX US 268 Fluid Catalytic Cracking

1 11 29 10 11 29 10 TX US 205 Isomerization

1 11 29 10 12 02 10 PDVSA Amuay 640

1 11 30 10 11 30 10 Chevron MS US 330 Fluid Catalytic Cracking


1 12 01 10 12 01 10 LA US 505

ConocoPhillips

Belle Chasse

ExxonMobil


Imperial Oil

Edmonton


Coffeyville Resources

Coffeyville

Motiva Enterprises



ConocoPhillips

LyondellBasell

Valero Energy

Corpus Christi

Venezuela


Pascagoula

ExxonMobil

Beaumont

ExxonMobil

Baton Rouge




1 12 01 10 12 01 10 BP Carson CA US 252

1 12 01 10 12 01 10 Benicia CA US 140 Fluid Catalytic Cracking

3 12 02 10 12 02 10 PDVSA El Palito 127

1 12 02 10 12 02 10 Joliet IL US 238 Utilities Production

3 10 *- 10 12 01 10 Pemex Mexico 330

1 10 25 10 11 27 10 BP Carson CA US 252 Catalytic Reforming1 11 26 10 *- *- *- TX US 345

1 11 29 10 11 29 10 TX US 070


1 11 30 10 11 30 10 Saraland AL US 085

1 12 01 10 12 01 10 TX US 205

1 12 01 10 12 03 10 Torrance CA US 150

2 12 01 10 12 04 10 Irving Oil St. John NB Canada 250 Fluid Catalytic Cracking


Corpus Christi


overy

Valero Energy

Venezuela


ExxonMobil

Salina Cruz


ExxonMobil

Beaumont


Alon USA Energy

Big Spring


Alon USA Energy

Big Spring

Shell Chemical


Valero Energy

Corpus Christi


ExxonMobil



1 12 05 10 12 07 10 Tesoro CA US 100

1 02 *- 11 03 *- 10 Shell Oil Martinez CA US 145 Hydrotreating1 04 20 11 05 20 10 Shell Oil Martinez CA US 145 Hydrocracking8 10 22 10 11 20 10 Chita Aichi Japan 152 Crude Distillation

8 11 15 10 11 20 10 Hokkaido Japan 133 Crude Distillation

8 11 23 10 11 23 10 Pertamina Balongan Indonesia 125 General Equipment

8 11 26 10 12 15 10 Kawasaki Japan 296

8 09 *- 11 *- *- *- Toa Oil Keihin Kawasaki Japan 110 Crude Distillation

8 05 15 11 06 05 11 Kubiki Japan 005 Crude Distillation

8 *- *- 11 *- *- *- Pertamina Indonesia 260

8 *- *- 13 *- *- *- Fuji Oil Chiba Japan 192 Crude Distillation

7 11 15 10 *- *- *- Kaduna Nigeria 110 General Equipment

7 11 21 10 *- *- *- Warri Nigeria 125 General Equipment

Wilmington


Idemitsu Kosan

Idemitsu Kosan

Tomakomai

TonenGeneral


Tesiki Topping Plant

Balikpapan

Kalimantan


Sodegaura




4 09 *- 10 *- *- *- 406 Fluid Catalytic Cracking

1 11 10 10 11 19 10 Hess NJ US 070 Fluid Catalytic Cracking

1 11 18 10 11 19 10 BP Carson CA US 252

1 11 20 10 11 20 10 LA US 505

1 11 20 10 11 23 10 Houston TX US 268

1 11 20 10 11 21 10 KS US 135

1 11 23 10 11 24 10 Joliet IL US 238

1 11 24 10 11 24 10 IL US 306 Fluid Catalytic Cracking

1 11 24 10 11 24 10 TX US 345

1 11 24 10 11 24 10 UT US 030 General Equipment

Royal Dutch Shell

Pernis, Rotterdam

Netherlands

Port Reading


ExxonMobil

Baton Rouge


LyondellBasell


Frontier Oil

El Dorado


ExxonMobil


ConocoPhillips

Wood River

ExxonMobil

Beaumont


Big West Oil

Salt Lake City




1 11 26 10 11 26 10 Shell Oil Martinez CA US 145

1 11 26 10 11 26 10 Tesoro Kapolei HI US 094

1 11 27 10 11 27 10 Borger TX US 146

1 09 22 10 11 23 10 Linden NJ US 238

1 10 15 10 11 20 10 Detroit MI US 102

1 10 15 10 11 22 10 Lima OH US 162 Fluid Catalytic Cracking

1 10 15 10 11 22 10 Lima OH US 162 Coking

1 *- *- *- 11 24 10 Holly UT US 030

8 11 17 10 11 17 10 CPC Corp. Taiwan 270 Crude Distillation

8 10 08 10 11 13 10 Yokkaichi Japan 193 Crude Distillation

Total Petrochemicals

Port Arthur

Valero Energy

Port Arthur



ConocoPhillips


ConocoPhillips


Marathon Oil


Husky Energy

Husky Energy

Woods Cross


Kaohsiung

Showa Shell Sekiyu


8 10 25 10 11 19 10 India 660 Crude Distillation

8 11 20 10 12 *- 10 Sinopec Gaoqiao China 230 Crude Distillation

8 11 20 10 12 *- 10 Sinopec Gaoqiao China 230 Coking

8 11 20 10 12 *- 10 Sinopec Gaoqiao China 230 Hydrocracking

4 09 11 10 11 19 10 Sarpom Trecate Italy 230 Crude Distillation

6 10 15 10 11 14 10 Ruwais UAE 350 Vapor Recovery/Gas Plant

6 01 15 11 *- *- *- Ruwais UAE 350 Vapor Recovery/Gas Plant

5 *- *- 11 *- *- 11 MOL Hungary 161

5 *- *- 11 *- *- 11 MOL Hungary 161

Reliance Industries

Jamnagar

ExxonMobil

Abu Dhabi National Oil

Abu Dhabi

Abu Dhabi National Oil

Abu Dhabi

Százhalombatta


Százhalombatta



5 *- *- 11 *- *- 11 Slovnaft Slovakia 115

5 *- *- 11 *- *- 11 INA Rijeka Croatia 090

5 *- *- 11 *- *- *- INA Sisak Croatia 080

1 11 02 10 11 18 10 Lemont IL US 159 Fluid Catalytic Cracking

1 11 12 10 *- *- *- Sunoco PA US 330 Hydrotreating

1 11 12 10 11 12 10 TX US 285 Fluid Catalytic Cracking

1 11 13 10 11 13 10 Chevron MS US 330


1 11 15 10 11 15 10 TX US 205

2 11 15 10 11 15 10 Sarnia ON Canada 121

1 11 09 10 11 16 10 KS US 114

1 11 16 10 11 16 10 Convent LA US 227

Bratislava




Citgo Petroleum

Philadelphia

Motiva Enterprises

Port Arthur

Pascagoula


Alon USA Energy

Big Spring

Valero Energy

Corpus Christi


Imperial Oil



Coffeyville


Motiva Enterprises



1 11 16 10 11 16 10 BP TX US 451 General Equipment

1 11 17 10 11 17 10 Tacoma WA US 039 Sulfur Plant

1 11 17 10 *- *- *- Shell Oil WA US 149

1 11 18 10 11 19 10 Chevron CA US 243 Hydrotreating

1 11 04 09 11 15 10 UT US 013 Crude Distillation

1 10 15 10 11 *- 10 Chevron CA US 243 Fluid Catalytic Cracking

1 10 15 10 11 *- 10 Chevron CA US 243 Alkylation

3 10 *- 10 10 *- 10 Petrobras Cubatao Brazil 170

1 11 25 10 12 21 10 BP Carson CA US 252

3 10 *- 10 11 17 10 Petrobras Revap Brazil 241


6 10 15 10 11 *- 10 Kuwait 466 Hydrotreating

Texas City

US Oil & Refining

Anacortes


Richmond

Silver Eagle Refining

Woods Cross

Richmond

Richmond



Sao Jose dos

Campos

Visbreaking/Thermal Cracking

Kuwait National Petroleum

Mina Al-Ahmadi


4 *- *- 11 *- *- 11 Saras Sarroch Sardinia Italy 300 Hydrotreating

4 *- *- 11 *- *- 11 Saras Sarroch Sardinia Italy 300 Alkylation

4 *- *- 11 *- *- 11 Saras Sarroch Sardinia Italy 300 Hydrocracking

4 *- *- 11 *- *- 11 Saras Sarroch Sardinia Italy 300

4 *- *- 11 *- *- 11 Saras Sarroch Sardinia Italy 300 Crude Distillation

4 *- *- 11 *- *- 11 Saras Sarroch Sardinia Italy 300 Crude Distillation

4 *- *- 11 *- *- 11 Saras Sarroch Sardinia Italy 300 Catalytic Reforming


1 11 06 10 11 07 10 Borger TX US 146 Fluid Catalytic Cracking

1 11 06 10 11 06 10 TX US 345

1 11 08 10 *- *- *- Shell Oil Martinez CA US 145


Motiva Enterprises

Port Arthur

ConocoPhillips

ExxonMobil

Beaumont




1 11 09 10 11 09 10 KS US 114


1 11 10 10 11 11 10 TX US 157

1 11 10 10 11 10 10 Tesoro Martinez CA US 161

1 11 11 10 11 11 10 BP TX US 451 Hydrotreating

1 11 12 10 11 12 10 Joliet IL US 238

1 11 12 10 11 12 10 TX US 167 Waste Water Treatment

1 *- *- *- 11 12 10 Sarnia ON Canada 121 Utilities Production

1 08 *- 10 11 11 10 Baytown TX US 576 Crude Distillation

1 08 *- 10 11 11 10 Baytown TX US 576 Hydrotreating



Coffeyville


Motiva Enterprises

Citgo Petroleum

Corpus Christi

Aromatics Production/Recovery


Texas City

ExxonMobil


Valero Energy

McKee (Sunray)

Imperial Oil

ExxonMobil

ExxonMobil

ExxonMobil



1 08 *- 10 11 11 10 Baytown TX US 576

2 09 29 10 11 13 10 Irving Oil St. John NB Canada 250 Crude Distillation

2 09 29 10 11 13 10 Irving Oil St. John NB Canada 250 Catalytic Reforming

2 09 29 10 11 13 10 Irving Oil St. John NB Canada 250 Fluid Catalytic Cracking

2 09 29 10 11 13 10 Irving Oil St. John NB Canada 250 Sulfur plant

1 10 01 10 11 09 10 KS US 083

1 10 17 10 11 11 10 Joliet IL US 238

1 11 15 10 11 26 10 BP Carson CA US 252

ExxonMobil

ExxonMobil

Solvent Extraction and Deasphalting

National Cooperative Refining

McPherson


ExxonMobil




8 10 *- 10 11 *- 10 Sinopec Maoming China 270 Crude Distillation

8 10 *- 10 11 *- 10 Sinopec Maoming China 270 Coking

8 11 03 10 12 *- 10 CNOOC Huizhou China 240 Fluid Catalytic Cracking8 03 *- 11 04 *- 11 Daesan 310 Crude Distillation

8 05 05 11 06 05 11 SK Energy Ulsan 817 Crude Distillation

8 07 15 11 08 25 11 SK Energy Ulsan 817 Crude Distillation

8 05 *- 11 *- *- *- S-Oil Onsan 520 Crude Distillation

8 06 15 11 07 25 11 SK Energy Inchon 270 Crude Distillation

4 11 01 10 *- *- *- Total Antwerp Belgium 357

4 11 04 10 11 20 10 Total 147 Hydrocracking

4 11 04 10 11 19 10 Total Donges France 230 Fluid Catalytic Cracking1 04 02 10 10 04 10 Shell Oil WA US 149

3 10 05 10 10 29 10 PDVSA Amuay 640 Fluid Catalytic Cracking

Guangdong

Guangdong

Hyundai Oil

South Korea

South Korea

South Korea

South Korea

South Korea


Vlissingen

Netherlands

Anacortes


Venezuela


1 10 27 10 11 02 10 Rodeo CA US 120

1 10 26 10 *- *- *- Linden NJ US 238

1 11 02 10 11 02 10 Linden NJ US 238 Utilities Production

2 10 28 10 11 01 10 Sarnia ON Canada 071

1 10 30 10 10 30 10 TX US 096 Hydrotreating

1 11 01 10 11 01 10 Murphy Oil Superior WI US 033

1 11 01 10 11 01 11 CA US 080 General Equipment

1 11 02 10 11 02 10 Baytown TX US 576 Fluid Catalytic Cracking

1 11 03 10 11 03 10 IL US 306 General Equipment


1 11 03 10 11 03 10 Borger TX US 146 Fluid Catalytic Cracking

1 11 02 11 11 03 11 Tyler TX US 060 Sulfur Plant

1 11 04 10 11 04 10 Tesoro CA US 100 Hydrocracking

ConocoPhillips


ConocoPhillips


ConocoPhillips

Shell Canada


Valero Energy

Three Rivers


Valero Energy

Wilmington

ExxonMobil

ConocoPhillips

Wood River

Motiva Enterprises

ConocoPhillips

Delek Refining

Wilmington


1 11 04 10 *- *- *- CA US 088

1 09 07 10 11 06 10 LA US 247 Fluid Catalytic Cracking

1 10 04 10 11 01 10 Suncor Montréal QB Canada 130

1 *- *- *- 10 31 10 TX US 285 Fluid Catalytic Cracking

1 *- *- *- 10 31 10 CA US 139 Fluid Catalytic Cracking

1 11 01 10 11 15 10 CA US 139 Alkylation

2 11 02 10 *- *- *- Scotford AB Canada 100

1 11 05 10 *- *- *- Tesoro Martinez CA US 161

1 11 05 10 11 12 10 BP Carson CA US 252

1 11 30 10 12 *- 10 Holly Tulsa OK US 125

1 01 15 11 *- *- *- El Paso TX US 125

Alon USA Energy

Paramount


ConocoPhillips

Belle Chasse


Motiva Enterprises

Port Arthur

ConocoPhillips

Wilmington

ConocoPhillips

Wilmington

Shell Canada





Western Refining



1 *- *- 11 *- *- *- Gallup NM US 023

6 10 23 10 10 25 10 Rabigh 400

3 09 07 10 *- *- 11 Pemex Mexico 275 Hydrotreating

1 10 22 10 10 22 10 Joliet IL US 238

1 10 24 10 10 24 10 BP Whiting IN US 385 Sulfur Plant

1 10 24 10 10 24 10 Tyler TX US 060 Fluid Catalytic Cracking

1 10 24 10 10 24 10 Tyler TX US 060 Alkylation

1 10 25 10 10 25 10 Lemont IL US 159

1 10 27 10 10 27 10 Lemont IL US 159

1 10 25 10 10 25 10 Westlake LA US 239

Western Refining


Saudi Aramco

Saudi Arabia


Cadereyta

ExxonMobil


Delek Refining

Delek Refining

Citgo Petroleum


Citgo Petroleum


ConocoPhillips



1 10 26 10 10 27 10 Linden NJ US 238

1 10 26 10 10 26 10 LA US 083


1 10 22 10 10 27 10 Rodeo CA US 120

1 10 28 10 10 28 10 IL US 306

1 10 28 10 10 28 10 LA US 505

1 10 28 10 10 28 10 Lima OH US 162

1 10 28 10 10 28 10 Baytown TX US 576 Hydrocracking

2 10 28 10 10 28 10 Scotford AB Canada 100

ConocoPhillips


Alon USA Energy

Krotz Springs


Valero Energy

Port Arthur

ConocoPhillips


ConocoPhillips

Wood River


ExxonMobil

Baton Rouge


Husky Energy


ExxonMobil

Shell Canada



1 10 29 10 10 29 10 KS US 114

2 09 11 10 10 27 10 Suncor Sarnia ON Canada 085


1 10 12 10 10 23 10 Suncor AB Canada 135

1 10 16 10 10 23 10 Robinson IL US 204 Crude Distillation

1 10 27 10 10 27 10 TX US 205 Crude Distillation

1 01 *- 11 *- *- *- Houston TX US 268 Fluid Catalytic Cracking

1 01 *- 11 *- *- *- TX US 250 Crude Distillation

1 01 *- 11 *- *- *- TX US 250 Coking

1 01 *- 11 02 *- 11 Benicia CA US 140

1 03 *- 11 *- *- *- TX US 167 Hydrocracking

1 08 25 10 10 16 10 Baytown TX US 576 Hydrotreating

8 09 21 10 10 21 10 Japan 120 Crude Distillation

4 10 03 10 10 18 10 CEPSA Cadiz Spain 240 Crude Distillation8 10 12 10 10 19 10 Muroran Japan 180 Catalytic Reforming

8 10 12 10 10 19 10 Muroran Japan 180 Hydrotreating

8 10 21 10 11 21 10 Chita Aichi Japan 152


Coffeyville




Corpus Christi

Edmonton


Marathon Oil

Valero Energy

Corpus Christi

LyondellBasell

Valero Energy

Port Arthur

Valero Energy

Port Arthur

Valero Energy


Valero Energy

McKee (Sunray)

ExxonMobil

Idemitsu Kosan

Tokuyama

JX Holdings

JX Holdings

Idemitsu Kosan



8 08 *- 10 10 16 10 Cosmo Oil Sakai Japan 076 Coking

8 08 *- 10 10 16 10 Cosmo Oil Sakai Japan 076 Hydrotreating

8 08 *- 10 10 16 10 Cosmo Oil Sakai Japan 076 Hydrotreating

8 10 25 10 11 *- 10 India 660 Coking

7 02 *- 11 *- *- 11 Khartoum Sudan 050

4 03 *- 11 04 *- 11 Eni Gela Ragusa Italy 105

4 08 31 11 09 *- 11 BP Lingen Germany 086

5 10 *- 11 *- *- 11 BP Germany 264

3 10 16 10 10 18 10 Petrotrin 168

1 10 19 10 *- *- 10 KS US 114


Reliance Industries

Jamnagar




Gelsenkirchen


Pointe-a-Pierre

Trinidad and Tobago



Coffeyville


Valero Energy

Corpus Christi


1 10 19 10 10 19 10 CA US 080 General Equipment

1 10 20 10 10 20 10 Baytown TX US 576 General Equipment

1 10 21 10 10 21 10 Joliet IL US 238

1 10 21 10 *- *- 10 Baytown TX US 576 Crude Distillation

1 11 *- 10 *- *- *- LA US 247 Alkylation

1 10 15 10 *- *- *- Detroit MI US 102

1 10 15 10 11 25 10 Lima OH US 162 Coking

1 10 15 10 11 25 10 Lima OH US 162 Fluid Catalytic Cracking


1 *- *- 10 10 18 10 Sweeny TX US 247 Sulfur plant

1 *- *- 10 10 22 10 BP TX US 451 Hydrotreating

1 10 22 10 11 08 10 BP Carson CA US 252

1 09 30 10 10 14 10 Tesoro Martinez CA US 161 Fluid Catalytic Cracking

1 10 04 10 10 04 10 Shell Oil Martinez CA US 145

Valero Energy

Wilmington

ExxonMobil

ExxonMobil


ExxonMobil

ConocoPhillips

Belle Chasse

Marathon Oil


Husky Energy

Husky Energy

Motiva Enterprises

Port Arthur

ConocoPhillips

Texas City




1 10 05 10 10 14 10 Joliet IL US 238 Hydrotreating

1 10 09 10 10 09 10 Tesoro Martinez CA US 161 General Equipment

1 10 06 10 10 10 10 LA US 193 General Equipment

3 10 06 10 10 16 10 Hovensa St. Croix US 500 Fluid Catalytic Cracking


ExxonMobil

Chalmette Refining

Chalmette

Virgin Islands


Corpus Christi


1 10 09 10 10 09 10 Sinclair Oil Sinclair WY US 066 Sulfur Plant

1 10 09 10 10 09 10 Sinclair Oil Sinclair WY US 066 Sulfur Plant


1 10 14 10 10 *- 10 Linden NJ US 238 General Equipment

1 10 14 10 10 *- 10 KS US 114

1 10 14 10 10 *- 10 LA US 505

1 10 14 10 10 14 10 Tyler TX US 060 Fluid Catalytic Cracking

1 10 09 10 *- *- 10 Convent LA US 227 Sulfur Plant

2 10 12 10 10 25 10 AB Canada 187

1 10 13 10 10 20 10 BP Carson CA US 252

1 10 14 10 10 15 10 Tesoro CA US 100

1 10 16 10 10 17 10 Lima OH US 162 Utilities Production

Valero Energy

Three Rivers

ConocoPhillips


Coffeyville


ExxonMobil

Baton Rouge


Delek Refining

Motiva Enterprises

Imperial Oil

Edmonton



Wilmington


Husky Energy


3 08 *- 10 10 07 10 Ecuador 110 Crude Distillation

8 09 27 10 09 29 10 Kashima Japan 210 Fluid Catalytic Cracking

8 09 27 10 10 05 10 Negishi Japan 340 Fluid Catalytic Cracking

8 10 05 10 *- *- *- Cosmo Oil Sakai Japan 076 Fluid Catalytic Cracking

8 09 19 10 10 15 10 Negishi Japan 340 Crude Distillation

8 10 04 10 11 02 10 Japan 250 Crude Distillation

1 10 02 10 *- *- *- Westlake LA US 239

1 10 02 10 10 02 10 Sweeny TX US 247 General Equipment

1 10 04 10 10 05 10 Chevron UT US 045 Sulfur Plant

1 10 05 10 10 05 10 Borger TX US 146 Coking

1 10 06 10 10 06 10 BP Toledo OH US 152

1 10 06 10 10 06 10 Rodeo CA US 120

1 10 07 10 10 07 10 Deer Park TX US 327

1 10 08 10 *- *- 10 Norco LA US 310 General Equipment

1 10 02 10 10 04 10 BP TX US 451 Catalytic Reforming

2 10 04 10 *- *- *- Montréal QB Canada 121

Petroecuador

Esmeraldas

Kashima Oil

JX Holdings

JX Holdings

JX Holdings

Mizushima

ConocoPhillips


ConocoPhillips

Salt Lake City

ConocoPhillips


ConocoPhillips


overy

Deer Park Refining


Valero Energy

Texas City

Shell Canada



8 07 25 10 10 14 10 Mailiao Taiwan 540 Crude Distillation

8 10 05 10 10 12 10 Cosmo Oil Sakai Japan 076 Fluid Catalytic Cracking

8 10 09 10 11 11 10 CPC Corp. Talin Taiwan 300 Crude Distillation

8 11 01 10 12 06 10 CPC Corp. Taoyuan Taiwan 200 Hydrotreating

8 12 *- 10 *- *- *- CPC Corp. Taoyuan Taiwan 200 Crude Distillation

8 11 *- 10 11 *- 10 Sinopec Maoming China 270 Coking

8 12 *- 10 01 *- 11 Sinopec Jiujiang Jiangxi China 080 Fluid Catalytic Cracking

8 03 *- 11 06 *- 11 Caltex Kurnell Australia 106 Fluid Catalytic Cracking

7 10 07 10 10 13 10 Durban 119

4 *- *- 11 *- *- 11 406

4 09 *- 10 10 *- 10 406

Formosa Petrochemical

Guangdong

Engen Petroleum

South Africa


Royal Dutch Shell

Pernis, Rotterdam

Netherlands


Royal Dutch Shell

Pernis, Rotterdam

Netherlands



1 11 04 09 02 17 10 UT US 013 Crude Distillation

7 10 01 10 11 15 10 Indeni Oil Ndola Zambia 024

8 08 27 09 09 28 09 Cosmo Oil Sakai Japan 076 Crude Distillation

8 03 *- 11 04 *- 11 Dalian China 160

1 09 13 10 *- *- *- Chevron MS US 330 Hydrocracking

1 09 24 10 09 25 10 TX US 070

1 09 25 10 *- *- 10 Sunoco PA US 330 Hydrotreating

1 09 27 10 *- *- 10 TX US 225 General Equipment

1 09 27 10 *- *- 10 TX US 250 General Equipment

Silver Eagle Refining

Woods Cross


West Pacific Petrochemicals


Pascagoula

Alon USA Energy

Big Spring


Philadelphia

Valero Energy

Texas City

Valero Energy

Port Arthur


1 09 27 10 09 27 10 Benicia CA US 140

1 09 27 10 09 27 10 Torrance CA US 150

1 09 28 10 09 29 10 Murphy Oil Meraux LA US 125


1 09 30 10 09 30 10 BP TX US 451 General Equipment

3 *- *- 10 09 30 10 Hovensa St. Croix US 500 Fluid Catalytic Cracking

1 09 27 10 09 27 10 BP TX US 451 Crude Distillation

1 09 28 10 10 04 10 BP Carson CA US 252

2 09 29 10 11 03 10 Irving Oil St. John NB Canada 250 Crude Distillation2 09 29 10 11 03 10 Irving Oil St. John NB Canada 250 Catalytic Reforming2 09 29 10 11 03 10 Irving Oil St. John NB Canada 250 Fluid Catalytic Cracking2 09 29 10 11 03 10 Irving Oil St. John NB Canada 250 Sulfur plant1 09 30 10 10 05 10 Shell Oil Martinez CA US 145 Fluid Catalytic Cracking

Valero Energy


ExxonMobil




Corpus Christi

Texas City

Virgin Islands

Texas City



1 10 01 10 10 01 10 TX US 279 Crude Distillation



1 10 01 10 10 01 10 TX US 279



Corpus Christi


Corpus Christi


Corpus Christi


Corpus Christi

Aromatics Production/Recovery


Corpus Christi


**Regions: (1) United States, (2) Canada, (3) Latin America & Caribbean, (4) Western Europe, (5) Eastern Europe, (6) Middle East, (7) Africa, (8) Asia-Pacific

Unit / plant Additional details

FCCU N.A. N.A. p 27-Dec-10

FCCU 024.0 024.0 p 27-Dec-10

HCU N.A. N.A. p 27-Dec-10

Reformer N.A. N.A. p 27-Dec-10

CDU N.A. N.A. u 27-Dec-10

FCCU N.A. N.A. u 27-Dec-10

how All. The drop-down buttons will appear in black.

Unit size, K b/d

Production impact, K

b/d

Planned/ unplanned

Date of last update

An FCCU will be closed for around 40 days of planned work in early Jan. 2011. Another FCCU will be shut for maintenance in 2012.

A four-week turnaround that commenced at the end of Nov. is expected to be completed at the end of Dec.

*Several units, including an HCU and a reformer, will undergo planned maintenance this autumn, according to sources close to the refinery.

*Several units, including an HCU and a reformer, will undergo planned maintenance this autumn, according to sources close to the refinery.

*The No. 2B CDU was restarted as of Nov. 22, and an FCCU, the No. 3 CDU, and secondary units are expected to be back online by mid-Dec. The entire refinery was knocked offline by a power outage.



CDU N.A. N.A. u 27-Dec-10

FCCU 200.0 200.0 N.A. p 27-Dec-10

FCCU 035.5 N.A. N.A. u 27-Dec-10

Maintenance N.A. N.A. p 27-Dec-10

CDU 075.0 147.0 u 27-Dec-10

CDU 050.0 147.0 u 27-Dec-10



Maintenance on an unspecified process unit slightly impacted production.

*The refinery was temporarily halted by a power outage on Dec. 7. The No. 6, 75K-b/d CDU, which was shut down by the power failure, was restarted on Dec. 13, while the No. 5, 50K-b/d CDU and other primary refining units were restarted on Dec. 18.

*The refinery was temporarily halted by a power outage on Dec. 7. The No. 6, 75K-b/d CDU, which was shut down by the power failure, was restarted on Dec. 13, while the No. 5, 50K-b/d CDU and other primary refining units were restarted on Dec. 18.

The FCCU, which was taken down on Dec. 7 for a repair, was expected to be restarted earlier in the month; however, Valero reported on Dec. 20 that the FCCU will remain shut until after a refinery turnaround is completed. The maintenance is slated to start in Jan. 2011 and span 36 days.


SRU N.A. N.A. u 27-Dec-10

HTU 045.0 045.0 u 27-Dec-10

FCCU 031.0 031.0 The unit was shut for repairs. u 27-Dec-10

VGO unit 100.0 100.0 N.A. p 27-Dec-10

Fire N.A. N.A. u 27-Dec-10

Pipeline N.A. N.A. u 27-Dec-10


Flare N.A. N.A. u 27-Dec-10

Excess emissions occurred at the SCOT-4 SRU tail gas incinerator, due to a failed flame scanner at the unit's inline heater. Production was not affected. Emissions also occurred when the unit was restarted on Dec. 19.

An explosion at a heavy oil upgrader hit a 45K-b/d HTU, killing one worker and injuring six others. The unit continued to operate, despite the impact, although rates at the related vacuum residue desulfurizing unit were lowered. Korean media reported that a gas leak during maintenance was the cause of the explosion, but the company did not confirm this report.

A fire occurred, due to a leak. Four workers were injured in the blaze, which was later extinguished. The incident did not impact production.

The refinery was closed on or around Dec. 22, due to sabotage on Dec. 6 at a pipeline supplying crude to the plant.

The refinery was closed on or around Dec. 22, due to sabotage on Dec. 6 at a pipeline supplying crude to the plant.

Sulfur dioxide releases occurred at the refinery as a result of maintenance activity.


WGC N.A. N.A. u 27-Dec-10



Alkylation unit N.A. N.A. u 27-Dec-10


Valve N.A. N.A. u 27-Dec-10


Flare N.A. N.A. u 27-Dec-10


A wet gas compressor tripped offline. The incident led to the release of sulfur dioxide.

A small fire and a unit upset occurred late in the day. The blaze was quickly contained, with no impact to production.

An FCCU and an alkylation unit were knocked offline, but the units were restarted and returned to normal operations later in the day.

An FCCU and an alkylation unit were knocked offline, but the units were restarted and returned to normal operations later in the day.

A unit upset and fire led to flaring of hydrogen sulfide and sulfur dioxide.

Emissions were released from the SRU and a SCOT unit, due to a faulty solenoid valve. The glitch forced the closure of the process air valves.

An explosion and fire at a tanker truck parked on refinery grounds threatened nearby tanks, but firefighters were able to extinguish the blaze before it spread to the tanks. Damage to the rest of the refinery was said to be minimal.

Sulfur dioxide was released from a flare, due to an electrical malfunction. Power was restored, and affected units were restarted shortly thereafter.

A propane leak on a gas cracker line was expected to be repaired on Dec. 23.



Maintenance N.A. N.A. N.A. p 27-Dec-10

CDU 150.0 150.0 u 20-Dec-10

CDU 086.0 086.0 N.A. p 20-Dec-10

FCCU 025.5 025.5 N.A. p 20-Dec-10

CDU 240.0 240.0 N.A. p 20-Dec-10

CDU 165.0 165.0 N.A. p 20-Dec-10

Outage N.A. 116.0 u 20-Dec-10

HCU N.A. N.A. u 20-Dec-10

Hydrogen unit N.A. N.A. u 20-Dec-10

Outage N.A. 094.0 u 20-Dec-10

Reformer N.A. N.A. p 20-Dec-10

Hydrogen unit N.A. N.A. p 20-Dec-10

A hydrocracker at the east plant was closed for repairs, leading to emissions. The unit has been closed several times in the past week for repairs on an exchanger and piping.

The No. 4 CDU was restarted following a shutdown due to a minor leak.

The refinery, which was taken offline for an unplanned shutdown on Oct. 30, was expected to restart late in the week to Dec. 18 or in the following week. A leak in the plant's cooling system resulted in damage to several units, including the coker.

The Unipetrol-owned refinery suffered a small fire that damaged a hydrocracker.

Two weeks of flaring could occur while repairs are made to a hydrogen unit.

The entire refinery was knocked offline by a technical glitch.

*Processing units, including a reformer and a hydrogen plant, were down for maintenance.

*Processing units, including a reformer and a hydrogen plant, were down for maintenance.


Maintenance N.A. 119.0 N.A. p 20-Dec-10



Outage N.A. N.A. u 20-Dec-10


Compressor N.A. N.A. u 20-Dec-10





FCCU N.A. N.A. p 20-Dec-10

Boiler N.A. N.A. p 20-Dec-10


Flare N.A. N.A. p 20-Dec-10

Maintenance N.A. N.A. N.A. p 20-Dec-10

The southern part of the refinery will be shut for planned work in 1Q 2011.

Power was fully restored over the weekend of Dec. 11-12, following a small fire at an electrical switching station on Dec. 9 that resulted in flaring and power outages in some areas of the refinery. The plant is expected to be back at planned rates by Dec. 14.

Unplanned flaring was reported.

H2S was released during a brief equipment failure.

An outage at a wet gas compressor caused flaring.

An equipment failure resulted in an emergency flare and the release of sulfur dioxide.

A process unit overpressurized, leading to the release of "sour hydrocarbons."

A flash fire erupted at the west plant.

An operational upset resulted in the release of sulfur dioxide.

The planned shutdown of an FCCU for compressor repairs was expected to require flaring.

Emissions occurred during maintenance at an ESP boiler.

The unit was shut for maintenance on an exchanger.

The refiner warned of planned flaring.


CDU 050.0 N.A. p 13-Dec-10

Coker 028.0 N.A. p 13-Dec-10

CDU 045.0 N.A. p 13-Dec-10

FCCU 070.0 N.A. u 13-Dec-10

Electrical N.A. N.A. u 13-Dec-10

Pump N.A. N.A. u 13-Dec-10



HTU N.A. N.A. u 13-Dec-10


Electrical N.A. N.A. A power outage occurred. u 13-Dec-10

*The refiner postponed planned maintenance on a CDU and a coker from Dec. 2010 to March 2011, due to a delay in materials delivery and high diesel demand.

*The refiner postponed planned maintenance on a CDU and a coker from Dec. 2010 to March 2011, due to a delay in materials delivery and high diesel demand.

The older, 45K-b/d CDU will be stopped for planned work in Jan. 2011. The work was delayed from 2Q 2010, as a new, 65K-b/d CDU commenced production in June.

The unit was shut down to repair a wet gas compressor.

Heavy rains on Dec. 2 caused a power outage and forced the refinery to close, but the plant was operating at 70% of capacity as of Dec. 7.

An equipment failure on a pump caused a benzene release.

XOM reported emissions of benzene and hydrogen sulfide due to an equipment failure.

The refinery experienced instrumentation problems.

Sulfur dioxide escaped from a flare due to cold weather. Citgo halted the flaring and performed a partial shutdown involving an HTU.

A compressor tripped offline, causing a benzene release.


Tank N.A. N.A. u 13-Dec-10





Outage N.A. 110.0 N.A. u 13-Dec-10

Sulfur plant N.A. N.A. u 13-Dec-10


FCCU N.A. N.A. N.A. p 13-Dec-10Maintenance N.A. N.A. N.A. p 13-Dec-10

Ultracracker N.A. N.A. p 13-Dec-10

HTU N.A. N.A. p 13-Dec-10

Flaring occurred from a PSV on a tank. The refiner adjusted operations to decrease pressure in the tank.

An upset in a process unit caused flaring and forced Tesoro to depressurize the unit, but was not expected to prevent the refinery from meeting supply commitments.

Nitric oxide was released from the ammonia system on the C train.

An emissions release occurred due to unknown causes.

An unidentified unit was closed to repair a leaking pipe.

Two sulfur plants tripped offline, resulting in flaring.

Ethylene and nitrogen oxide were released from a flare, due to a failure at an electrical breaker, which led to the shutdown of a coker wet gas compressor.

An Ultracracker and a catalytic feed hydrotreater resumed operations on Dec. 8. Flaring was expected to occur during the restarts and last until Dec. 12.

An Ultracracker and a catalytic feed hydrotreater resumed operations on Dec. 8. Flaring was expected to occur during the restarts and last until Dec. 12.


CDU 075.0 075.0 u 6-Dec-10

CDU 100.0 N.A. p 6-Dec-10

Fire N.A. 012.0 u 6-Dec-10

Tank N.A. N.A. u 6-Dec-10


CDU 150.0 150.0 p 6-Dec-10


FCCU 102.0 061.0 u 6-Dec-10

The No. 6 CDU was restarted following several days of minor repair work.

The unit and related facilities will be shut in late Feb. 2011 for scheduled maintenance.

A fire broke out at a distillation plant; the blaze was extinguished shortly thereafter. The fire was the third to occur at the refinery in the space of a year; in Dec. 2009, two tank fires broke out within five days of one another. An investigation into the most recent incident has been launched.

An accident occurred at a bitumen tank, which must be cooled, emptied, and repaired. Refinery production was not impacted by the incident.

Some production units were temporarily shut down.

The unit will be closed for about 45 days of maintenance, according to a trade source.

The refinery will be shut for maintenance from late April 2011 to the end of May. The closure will significantly impact the production and supply of naphtha.

*Rates at the FCCU were cut to 60% of capacity on Nov. 23 as the restart of the alkylation unit was delayed by around two weeks, to the end of Nov. Maintenance on the units began in Aug.; the FCCU was restarted in Oct. and is expected to return to full rates over the weekend of Dec. 4-5.


Alkylation unit N.A. N.A. u 6-Dec-10

Electrical N.A. N.A. u 6-Dec-10


SRU N.A. N.A. u 6-Dec-10




FCCU N.A. N.A. N.A. u 6-Dec-10

Butamer unit N.A. N.A. u 6-Dec-10

Electrical N.A. 640.0 u 6-Dec-10

FCCU N.A. N.A. N.A. u 6-Dec-10

Valve N.A. N.A. u 6-Dec-10

Fuel gas treater N.A. N.A. u 6-Dec-10

*Rates at the FCCU were cut to 60% of capacity on Nov. 23 as the restart of the alkylation unit was delayed by around two weeks, to the end of Nov. Maintenance on the units began in Aug.; the FCCU was restarted in Oct.

A power outage occurred as a result of a glitch at a third-party electricity provider. The incident forced the temporary closure of some units. One of the units suffered an additional upset during a restart attempt.

Flaring and steam venting occurred.

SRU No. 3 tripped, leading to the release of hydrogen sulfide and sulfur dioxide.

An equipment failure and unit malfunction resulted in the release of benzene.

A malfunction resulted in the release of sulfur dioxide.

Unplanned emissions at the unit were reported.

Butamer unit No. 36 in the west plant was closed to repair a leak at the boiler feed water system.

An electrical problem forced the temporary closure of the plant.

A leaking valve at the coker gas plant resulted in flaring.

The refiner isolated a failure at one of the plant's fuel gas treating units. The unit is being restored to normal rates, and all customer needs are being met.



Hydrogen unit N.A. N.A. u 6-Dec-10



Boiler N.A. N.A. u 6-Dec-10


Reformer N.A. N.A. N.A. p 6-Dec-10Maintenance N.A. N.A. N.A. p 6-Dec-10


Compressor N.A. N.A. p 6-Dec-10




RFCCU N.A. N.A. N.A. p 6-Dec-10

Emissions occurred after a leak was located on a line between the process units and a pump. The leak was isolated and workers blocked the line to stop the flaring.

A hydrogen unit was briefly knocked offline, due to an electrical mishap.

The unit tripped, resulting in flaring.

Heavy rains forced refinery processing to a minimum, but later improvement in the weather allowed processing units to resume normal operations.

A boiler malfunction resulted in overpressurization of another unit and flaring. The problem was isolated, and production was minimally impacted.

Several units, including one of the catalytic units, an HDS, and a viscosity reducer, were restarted from maintenance.

Excess opacity occurred. The refiner said the incident was the result of a test to see if a different configuration would lower opacity overall.

Maintenance and emissions associated with a high-stage compressor were reported.

Sulfur dioxide was released through an incinerator during a turnaround.

A planned release from the flare and heaters occurred.

Minor maintenance work and planned flaring occurred.



HTU N.A. N.A. N.A. p 6-Dec-10HCU N.A. N.A. N.A. p 6-Dec-10CDU 160.0 160.0 u 29-Nov-10

CDU 140.0 140.0 N.A. u 29-Nov-10

Pump N.A. N.A. A pumping unit was repaired. u 29-Nov-10

Outage N.A. N.A. u 29-Nov-10

CDU 120.0 120.0 u 29-Nov-10

CDU 005.0 005.0 N.A. p 29-Nov-10

Maintenance N.A. 260.0 p 29-Nov-10

CDU 140.0 140.0 p 29-Nov-10

Pipeline N.A. N.A. u 29-Nov-10

Pipeline N.A. N.A. u 29-Nov-10

Planned maintenance at select areas of the refinery will result in expected flaring.

The unit was restarted following a closure related to poor margins.

The refiner reported a problem with an unspecified secondary that is expected to reduce middle distillate exports.

The CDU will be permanently closed by Sept. 2011, as a result of weak domestic demand.

The plant will be closed for scheduled maintenance in mid-2011.

The unit will undergo planned work in 2013. Fuji decided to skip maintenance on the unit in 2011.

The plant was forced to shut down after militant sabotage damaged the Warri-Escravos pipeline, which feeds crude to the refinery. The shutdown is not expected to impact supplies to fuel stations.

The refinery was forced to shut down after militant activists blew up the Warri-Escravos pipeline, which feeds crude to the plant. The shutdown is not expected to impact supplies to fuel stations.


FCCU N.A. N.A. p 29-Nov-10

FCCU 070.0 N.A. u 29-Nov-10



Electrical N.A. N.A. u 29-Nov-10


Maintenance N.A. N.A. p 29-Nov-10

FCCU N.A. N.A. u 29-Nov-10

Fire N.A. N.A. u 29-Nov-10

Pump N.A. N.A. u 29-Nov-10

Shell has delayed the planned restart of an FCCU that was closed for maintenance in Sept., the company reported on Nov. 26.

The unit was repaired after being knocked offline by a power outage.

A process upset may have resulted in an H2S release the following day.

A pinhole leak on a distillate line in a processing unit was discovered. The leak allowed light coker naphtha to escape.

The refinery experienced a power outage on Nov. 20, due to an equipment failure at its electricity supplier, but the plant was restarted on Nov. 22. However, the refinery witnessed a small fire in an overhead line carrying diesel during the restart process on Nov. 23. The restart continued, despite the fire.

Flaring of H2S occurred due to an equipment failure.

Brief maintenance resulted in flaring.

Operations at an FCCU were suspended after the unit tripped offline and emitted more than 500 lb (227 kg) of SO2.

A small fire occurred at a processing area, but it was extinguished within half an hour, and the refinery continued to operate.

Hydrogen fluoride was released due to a failure on a pump in an allocation unit. The pump was shut to contain the release.


SRU N.A. N.A. u 29-Nov-10

Compressor N.A. N.A. u 29-Nov-10





Maintenance N.A. N.A. N.A. p 29-Nov-10

FCCU N.A. N.A. N.A. p 29-Nov-10

Coker N.A. N.A. N.A. p 29-Nov-10


CDU 100.0 N.A. u 22-Nov-10

CDU 075.0 075.0 N.A. p 22-Nov-10

An air compressor trip forced the temporary shutdown of an SRU.

Flaring from a wet gas compressor was reported after the unit, which is located at the saturated gas recovery plant, received light ends material from an unknown source. Production was not affected by the incident.

Natural gas and smoke were released at the refinery.

Tesoro reported an SO2 release due to a power outage. Power was quickly restored, and refinery operations were not impacted.

Emissions were reported after a process upset. The emissions were routed to a control device.

The refinery was restarted after longer-than-anticipated maintenance was completed.

A fire erupted at a pipe associated with the No. 7 CDU. The incident was quickly brought under control and operations were not impacted; however, two contract workers suffered slight burns.


CDU 330.0 330.0 N.A. p 22-Nov-10

CDU 160.0 160.0 p 22-Nov-10

Coker N.A. 160.0 p 22-Nov-10

HCU N.A. 160.0 p 22-Nov-10

CDU N.A. 150.0 u 22-Nov-10

Condensate train 140.0 N.A. p 22-Nov-10

Condensate train 140.0 N.A. p 22-Nov-10



*A CDU will be taken offline for a maintenance program that will last at least 35 days. The start of the work was delayed from Nov. 8. Other units, including a coker and an HCU, will also be closed during the work.



XOM halted jet fuel output at the plant on Sept. 13 after the CDU caught fire on Sept. 11, marking the second blaze in less than two weeks. The refinery was gradually ramping up rates by Nov. 19.

A condensate train and gasoline production plant were being restarted from maintenance.

One of the two 140K-b/d condensate trains will be shut from mid-Jan. 2011 for planned work.

Gasoline units will see planned maintenance in 2Q 2011.

Diesel units will see planned maintenance in 3Q 2011.






HDS N.A. N.A. u 22-Nov-10



ESP N.A. N.A. u 22-Nov-10


Fire N.A. N.A. u 22-Nov-10



Maintenance will be carried out at gasoline and diesel units during 2Q 2011.

Gasoline and diesel plants will see planned work in 2Q 2011.

During 4Q 2011, gasoline and diesel units will undergo work.

A brief fire knocked offline the FCCU. The unit remained offline until minor repairs were made.

A worker was injured in a fire at an HDS unit. The unit, located in the Point Breeze section of the refinery, had been under turnaround for 10 days before the blaze erupted.

Various blowers shut down while circulating catalyst, causing opacity at an FCCU.

An equipment failure resulted in a leak in a process line.

Excess opacity was caused by an upset at the electrostatic precipitator (ESP). A restart of the ESP resulted in boiler emissions from an FCCU.

Flaring was caused by excess pressure at a vessel in the east plant.

A small fire broke out and was extinguished. No impact to production was seen.

Emissions were released during a restart of the refinery on Nov. 16. It was previously reported that repairs to the plant were being made on Nov. 9.

A unit upset led to the release of sulfur dioxide and hydrogen sulfide.




Flare N.A. N.A. u 22-Nov-10

HTU N.A. N.A. u 22-Nov-10

VDU N.A. N.A. u 22-Nov-10

FCCU N.A. N.A. N.A. p 22-Nov-10

Alkylation unit N.A. N.A. N.A. p 22-Nov-10


Flare N.A. N.A. p 22-Nov-10

Cracker N.A. N.A. N.A. p 22-Nov-10

CDU 050.0 050.0 p 15-Nov-10

Naphtha HDS N.A. N.A. p 15-Nov-10

A sour water leak from a compressor in Power Unit 2 did not affect production.

An operator error at the SRU resulted in flaring of sulfur dioxide.

Erosion on the flare line resulted in the release of hydrogen sulfide. Shell is preparing to install a clamp over the line.

Flaring was reported due to a compressor outage, which knocked offline an HTU.

The firm prepared to restart a VDU that has been shut since a pipe explosion on Nov. 4, 2009. Several other units are still offline following the blast.

Maintenance was carried out at distillation and hydrotreating units.

Planned flaring is expected to occur from Nov. 25-Dec. 21. The refiner previously stated that flaring would also occur from Nov. 15-26.

The No. 5 CDU was be offline while planned work was carried out on secondary units.

Two gasoline-making units that were shut for two weeks of planned work in mid-Oct. are still closed as of Nov. 10, as maintenance is taking longer than expected, the company said.


DSU N.A. N.A. p 15-Nov-10

Alkylation unit N.A. N.A. p 15-Nov-10

HCU N.A. N.A. p 15-Nov-10

Visbreaker N.A. N.A. p 15-Nov-10

Topping unit N.A. N.A. p 15-Nov-10

VDU N.A. N.A. p 15-Nov-10

Reformer N.A. N.A. p 15-Nov-10

Regenerator N.A. N.A. u 15-Nov-10




*Maintenance will be performed in 1Q 2011 on two desulfurization units, an alkylation unit, and a mild hydrocracker.



*In 2Q 2011, a visbreaker, a topping unit, and a vacuum unit will undergo planned work.



In 4Q 2011, runs will be cut at a catalytic reformer during scheduled work.

Emissions occurred as the FCCU regenerator was being loaded with fresh catalyst and preheated, in preparation for startup. The catalyst loading was halted, and operations were returned to normal.

A processing glitch at the unit led to emissions.

Emissions and an instrumentation failure were reported during a startup at the refinery. VOCs were released from a tank.

An equipment failure led to the release of SO2. The company said it was working to fix the problem.




Aromatics unit N.A. N.A. u 15-Nov-10


RHTU N.A. N.A. u 15-Nov-10

Flare N.A. N.A. u 15-Nov-10

N.A. N.A. u 15-Nov-10

Boiler N.A. N.A. N.A. u 15-Nov-10

CDU N.A. N.A. p 15-Nov-10

HTU N.A. N.A. p 15-Nov-10

Hydroformer N.A. N.A. p 15-Nov-10

Emissions associated with repairs at the plant were reported.

A compressor tripped offline, resulting in the release of SO2, NOX, and VOCs.

The BTX unit was brought back online one day after being shut due to a benzene leak from a suction valve on a pump.

A power outage abruptly shut down the refinery. Power was restored later that day, which allowed the refinery to begin the restart process.

Flaring was reported due to a frozen propane line linked to the residual hydrotreater.

Emissions occured due to a slight overpressurization in a vessel. Set point pressure was raised to stop the flaring.

Water treatment system

Sodium hydroxide was released from a water treatment system into the soil.

*A pipestill, a naphtha hydrotreater, a hydroformer, a hydrodesulfurization unit, and a deasphalter unit had been shut for planned work.




HDS N.A. N.A. p 15-Nov-10

N.A. N.A. p 15-Nov-10


Rheniformer N.A. N.A. p 15-Nov-10


Sulfur plant N.A. N.A. p 15-Nov-10

Maintenance N.A. 083.0 N.A. p 15-Nov-10


Flare N.A. N.A. Planned flaring is expected. p 15-Nov-10


Deasphalting unit


*Six weeks of scheduled work were carried out on the No. 3 CDU, the No. 3 Rheniformer, the FCCU, and the sulfur plant. The turnaround cost $72MM, according to Irving.




Maintenance was performed on a number of units. Production was slightly impacted.


CDU 050.0 086.7 p 8-Nov-10

Coker 036.7 086.7 p 8-Nov-10

FCCU 027.9 N.A. N.A. p 8-Nov-10CDU 110.0 110.0 N.A. p 8-Nov-10

CDU 260.0 260.0 N.A. p 8-Nov-10

CDU 060.0 060.0 N.A. p 8-Nov-10

CDU 240.0 240.0 N.A. p 8-Nov-10

CDU 200.0 200.0 N.A. p 8-Nov-10

Cracker N.A. N.A. u 8-Nov-10

HCU N.A. N.A. p 8-Nov-10

FCCU N.A. N.A. N.A. p 8-Nov-10Outage N.A. N.A. u 8-Nov-10

FCCU 104.0 N.A. u 8-Nov-10

*The two were closed from end-Oct. for maintenance that will last about 20 days, according to industry sources.

*The two were closed from end-Oct. for maintenance that will last about 20 days, according to industry sources.

The refinery was evacuated following a gas leak at a naphtha cracker, which has been offline since the end of Sept. for maintenance.

An HCU will be ramped down from Nov. 4-8 for maintenance through Nov. 20. Work includes catalyst change, inspections, and cleaning.

The refinery, which has been shut since an explosion that killed seven workers, began restarting on Oct. 4 and was partially restarted, including the CDU, as of Oct. 19, but was delayed due to a boiler problem over the weekend of Oct. 23-24. The plant is expected to reach planned rates by Nov. 13.

The unit was taken offline for repairs to fix problems with the unit's air distributor and regenerator.




Transformer N.A. N.A. u 8-Nov-10

Fire N.A. 071.0 u 8-Nov-10

DSU N.A. N.A. u 8-Nov-10


Compressor N.A. N.A. The unit tripped offline. u 8-Nov-10



Pump N.A. N.A. u 8-Nov-10



HCU N.A. N.A. u 8-Nov-10

The refinery was back to planned rates following the loss of steam and hydrogen supplies.

A portion of the refinery was still being restarted following complications from a power outage.

A transformer switched, forcing the refiner to reroute power to another transformer.

A fire forced the closure of the refinery. The blaze, which occurred at an unspecified processing unit, was due to a failed gasket.

A malfunction involving a valve at a DSU resulted in emissions.

An external power failure knocked a unit offline and resulted in emissions of sulfur dioxide and hydrogen sulfide.

Operations at an FCCU were briefly disrupted when oxygen from an outside provider was cut.

A wet gas compressor went down.

A release of ethylene occurred while pumps were being swapped.

A process upset at an FCCU resulted in emissions.

An isolated power blip at an SRU resulted in excess emissions of SO2.

A breakdown led to flaring, Tesoro said. Trade sources said the unit involved was an HCU.


Outage N.A. 040.0 u 8-Nov-10

FCCU 120.0 N.A. p 8-Nov-10

Maintenance N.A. 130.0 N.A. p 8-Nov-10



Alkylation unit N.A. N.A. p 8-Nov-10



Flare N.A. N.A. p 8-Nov-10



Alon shut down the 40K-b/d Long Beach part of the refinery due to poor economics, trade sources said. The Paramount part of the complex remains in operation, but at reduced rates.

The unit is expected to be restarted during the week to Nov. 6, according to sources close to the refinery. The unit, which went down for maintenance on or around Sept. 7, originally was expected to be restarted in the week Oct. 30.

The No. 3 FCCU commenced a restart on Oct. 31. Emissions related to the restart could last through Nov. 7.

*The refiner was wrapping up an overhaul at an FCCU and preparing to commence planned work at the FCCU's associated alkylation unit.

*The refiner was wrapping up an overhaul at an FCCU and preparing to commence planned work at the FCCU's associated alkylation unit.

The refiner said that maintenance is occurring at conversion units. The work is resulting in lower throughput.




Electrical N.A. 400.0 u 1-Nov-10

HTU 054.0 054.0 u 1-Nov-10




Alkylation unit N.A. N.A. u 1-Nov-10




Planned work will be performed during 4Q 2011.

A power outage forced the plant to shut down.

The coker gas oil HTU, which has been shut since a deadly explosion erupted at the refiner on Sept. 7, is expected to be restarted in early 2011. Previous reports stated that the unit was restarted later Sept.

An equipment failure was related to scheduled maintenance that commenced earlier. The glitch led to the release of NOX to the flare stack.

An SRU process frame tripped.

*Power was lost during a thunderstorm, which triggered malfunctions at an FCCU and an alkylation unit.

*Power was lost during a thunderstorm, which triggered malfunctions at an FCCU and an alkylation unit.

Instrumentation issues caused intermittent flaring.

A power outage led to equipment shutdowns and flaring.

A unit upset was followed by the release of SO2 and SO3.




Depropanizer N.A. N.A. u 1-Nov-10


Electrical N.A. N.A. A power blip led to flaring. u 1-Nov-10



N.A. N.A. u 1-Nov-10


A transformer failed on the afternoon of Oct. 26, cutting power to the under-maintenance plant. Electricity was restored the next day, and the plant was gradually powered up over the following days. The outage was expected to extend planned maintenance, delaying the restart of a CDU by about one month to late Nov. As of Oct. 29, the FCCU is still offline as the refiner assesses any damage that might have been caused by the power outage.

A power outage caused flaring.

A leak at a depropanizer cooler in a catalytic reformer did not impact production; the leak was quickly repaired. Emissions from the repairs are expected to continue for several days.

Flaring was reported on Oct. 27; the plant was still recovering from a loss of hydrogen and steam on Oct. 22.

An instrument failure led to flaring.

An unspecified equipment failure led to acid gas flaring.

Hydroconversion unit

A raffinate hydroconversion unit was taken offline to fix a leak. The shutdown of the unit resulted in flaring.

A unit malfunction was accompanied by evacuation alarms, but the incident was quickly brought under control and production was not impacted.




HCU N.A. N.A. N.A. p 1-Nov-10


CDU N.A. N.A. N.A. p 1-Nov-10


FCCU 110.0 N.A. N.A. p 1-Nov-10

CDU N.A. N.A. N.A. p 1-Nov-10

Coker N.A. N.A. N.A. p 1-Nov-10

Maintenance N.A. 140.0 p 1-Nov-10

HCU 030.0 N.A. N.A. p 1-Nov-10

Gofiner N.A. N.A. p 25-Oct-10

CDU 120.0 120.0 u 25-Oct-10

CDU N.A. N.A. N.A. p 25-Oct-10Reformer 036.0 N.A. u 25-Oct-10

DSU 065.0 N.A. u 25-Oct-10

Maintenance N.A. 152.0 u 25-Oct-10

An equipment malfunction resulted in excess emissions.

Planned work on a CDU compressor was not expected to impact production.

The plant will be closed for 36 days of work.

Planned work on several Gofiners is expected to last for several months.

The unti was shut due to weak demand.

*A reformer and a naphtha desulfurizer were closed due to a gas leak in the desulfurizer.

*A reformer and a naphtha desulfurizer were closed due to a gas leak in the desulfurizer.

The refinery commenced a one-month closure, prompted by sluggish domestic demand. Maintenance will be performed during the economic closure.


Coker 025.0 067.0 u 25-Oct-10

Gas oil HDS 025.0 067.0 u 25-Oct-10

Naphtha HDS 017.0 067.0 u 25-Oct-10

Coker 160.0 N.A. p 25-Oct-10

Maintenance N.A. N.A. p 25-Oct-10



Maintenance N.A. 264.0 p 25-Oct-10

Fire N.A. N.A. N.A. u 25-Oct-10

Outage N.A. N.A. u 25-Oct-10

Butamer unit N.A. N.A. p 25-Oct-10

*The unit was restarted, along with several others, following inspections that commenced in Aug.



The coker will be offline for about 15 days of routine maintenance from late Oct.

Major maintenance will be performed in Feb. 2011.

Unspecified units will be closed from March-April 2011 for planned maintenance.

The plant will be closed for around six weeks of inspections and maintenance from the end of Aug. 2011, according to sources close to the refinery.

The refinery will be closed for maintenance sometime during 4Q 2011, according to industry sources.

An unspecified unit was shut down after an equipment malfunction led to the release of materials to the flare. The unit will require repairs.

A leak at the butamer unit in complex 6 of the west plant was reported on Oct. 19 and fixed by Oct. 20. The incident and repair work was expected to have resulted in the release of butane, propane, VOGs, isobutene, CO, and NOX.


Compressor N.A. N.A. u 25-Oct-10


Flare N.A. N.A. u 25-Oct-10

CDU N.A. N.A. u 25-Oct-10

Alkylation unit N.A. N.A. p 25-Oct-10

Maintenance N.A. N.A. N.A. p 25-Oct-10

Coker N.A. N.A. N.A. p 25-Oct-10

FCCU N.A. N.A. N.A. p 25-Oct-10

TGTU N.A. N.A. p 25-Oct-10

Sulfur plant N.A. N.A. N.A. p 25-Oct-10

RHTU N.A. N.A. p 25-Oct-10

Flare N.A. N.A. p 25-Oct-10

FCCU N.A. N.A. u 18-Oct-10


A compressor tripped offline, triggering flaring. Production was not impacted.

Flaring was reported, due to a compressor trip at Booster Station 4.

An equipment failure resulted in flaring.

Also, a CDU (dubbed Pipestill 3) was undergoing a turnaround. Throughput at the unit has been reduced while work is performed on a booster station.

Work is expected to commence in Nov. on an alkylation unit.

Tail gas treating unit 2 was shut for several hours for maintenance to remove sulfur from the distribution manifold.

A residual hydrotreater resumed normal operations on Oct. 22. The unit had been down for maintenance.


An unplanned overhaul at an FCCU was extended by at least one week, trade sources noted. Tesoro originally said the unit was taken offline on Sept. 30 for around one week of work.

Flaring was reported amid repairs to the flare system.


HTU N.A. N.A. u 18-Oct-10

Tank N.A. N.A. u 18-Oct-10

Pipeline N.A. N.A. u 18-Oct-10

FCCU 145.0 N.A. u 18-Oct-10

Compressor N.A. N.A. p 18-Oct-10

A diesel HTU was knocked offline by a compressor fire on Oct. 5; repairs to the damaged HTU began on Oct. 7. The incident at the compressor led to the release of SO2 and NOX.

A fire at a sludge tank injured one worker. The blaze erupted while maintenance was being performed on the tank; production was not impacted.

A hydrogen sulfide leak from a pipe was repaired; the leak was said to have affected production. A worker collapsed and died while in the process of repairing the leak on Oct. 6, but it has yet to be determined if the death was related to the leaking gas. Operations were back to normal as of Oct. 14.

The 145K-b/d FCCU is anticipated to reach normal rates by the weekend of Oct. 16-17, after being closed on Oct. 6 by a weather-related power outage, and then later restarted on Oct. 8.

Flaring occurred when a wet gas compressor tripped offline at a heavy oil cracker at the west plant. The unit was quickly returned to service, and production was not affected.


SRU N.A. N.A. u 18-Oct-10

SCOT N.A. N.A. u 18-Oct-10

SRU N.A. N.A. u 18-Oct-10

Compressor N.A. N.A. p 18-Oct-10




SRU N.A. N.A. p 18-Oct-10




Boiler N.A. N.A. p 18-Oct-10

*Sinclair cut feed to the sulfur units and restarted the SCOT unit. The refiner stated in a regulatory filing, "Hydrocarbon carryover to the No. 3 and No. 4 SRUs caused the TTO on No. 3 to shut down, and the SCOT and TTO on No. 4 to shut down."

*Sinclair cut feed to the sulfur units and restarted the SCOT unit. The refiner stated in a regulatory filing, "Hydrocarbon carryover to the No. 3 and No. 4 SRUs caused the TTO on No. 3 to shut down, and the SCOT and TTO on No. 4 to shut down."

A glitch occurred at the No. 1 SRU; the upset did not impact production.

Flaring was reported, due to the loss of a compressor. Operations were curbed to reduce the flaring.

An unspecified equipment failure occurred after H2S was released.

An unspecified unit was shut down, due to a jet fuel leak on a pipeline.

The FCCU suffered a glitch. Workers stabilized the unit shortly thereafter.

An SRU was closed, which caused SO2 flaring.

Maintenance on unspecified units was scheduled.



A boiler was replaced at the refinery over the weekend of Oct. 16-17 as part of routine maintenance.


CDU N.A. 110.0 p 11-Oct-10

FCCU 035.5 N.A. N.A. u 11-Oct-10

FCCU 041.0 N.A. N.A. u 11-Oct-10

FCCU 024.0 N.A. N.A. u 11-Oct-10

CDU 150.0 150.0 N.A. p 11-Oct-10

CDU 140.0 140.0 N.A. p 11-Oct-10



SRU N.A. N.A. N.A. u 11-Oct-10

Coker N.A. N.A. u 11-Oct-10


Hydrogen unit N.A. N.A. u 11-Oct-10

Electrical N.A. N.A. u 11-Oct-10


Ultraformer N.A. N.A. p 11-Oct-10


The plant was closed down from Aug. to carry out a refurbishment at a CDU.

An emergency shutdown of a unit was performed. The incident caused flaring, which resulted in a small grass fire.

A gas compressor was shut to repair a leak in a hydrogen quench line supplying reactor No. 4.

The unit malfunctioned, triggering flaring.

A process unit upset resulted in the release of H2S and SO2.

Flaring and a release of SO2 occurred due to the shutdown of a third-party hydrogen plant.

A power outage caused flaring.

A glitch with a coupling at a reformer hydrogen compressor impacted production.

Ultraformer No. 3 was restarted, following a maintenance closure. The restart process was slated to last three days.

A four-week maintenance closure commenced on or around Oct. 4.


CDU 180.0 180.0 u 11-Oct-10

FCCU 024.0 N.A. N.A. u 11-Oct-10

CDU 100.0 100.0 N.A. p 11-Oct-10

RDSU 030.0 N.A. N.A. p 11-Oct-10

CDU 100.0 100.0 N.A. p 11-Oct-10

Coker 036.7 N.A. N.A. p 11-Oct-10

FCCU 023.3 N.A. p 11-Oct-10

FCCU 021.5 N.A. p 11-Oct-10

Electrical N.A. 119.0 p 11-Oct-10



The last of the plant's three 180K-b/d CDUs was restarted after an oil leak sparked a fire at a residual desulfurization unit.

The unit will be closed for more than 40 days of planned work.

One of the two 21.5K-b/d FCCUs will be closed for scheduled work.

The refinery suffered a power failure and saw complications during a restart attempt.

Shell said on Oct. 15 that it has postponed maintenance on a hydrocracker to spring 2011; the work had been scheduled to take place in 4Q 2010.

Units at the plant that were shut in Sept. will be restarted by the end of Oct., to boost fuel output in response to strikes over pension reforms in France, which have crippled the country's refining industry.


CDU 013.0 N.A. u 4-Oct-10


CDU 080.0 080.0 N.A. p 4-Oct-10


HCU N.A. N.A. u 4-Oct-10





The No. 1 CDU, which was damaged in a pipe explosion, commenced a restart on Feb. 17. After the CDU reaches planned rates, the refiner will restart, one by one, the VDU, the SRU, and the reformer. The distillate dewaxing unit, where the explosion occurred, is expected to be restarted following the recent conclusion of an investigation into the incident, Silver Eagle said on Sept. 27.

The plant will be shut for 45 days of annual maintenance. Stocks are said to be adequate to cover requirements.

The refiner plans to carry out a major, 45-day turnaround in March and April 2011. The work is performed once every four years.

The unit was hit by a fire; the fire was quickly extinguished, and no other units were impacted.

Emissions occurred due to a heavy thunderstorm.

A diesel hydrotreater unit was shut, due to an upset that resulted in the release of a diesel mist into the atmosphere.

A compressor malfunction occurred in Complex 7 of the refinery, causing flaring.

A wet gas compressor tripped in the delayed coker, but it did not impact production.


Fire N.A. N.A. u 4-Oct-10


Electrical N.A. N.A. u 4-Oct-10


Pipeline N.A. N.A. u 4-Oct-10


CDU N.A. N.A. p 4-Oct-10


CDU N.A. N.A. N.A. p 4-Oct-10Rheniformer N.A. N.A. N.A. p 4-Oct-10

FCCU N.A. N.A. N.A. p 4-Oct-10Sulfur plant N.A. N.A. N.A. p 4-Oct-10

FCCU N.A. N.A. p 4-Oct-10

A small fire was extinguished at the plant; the incident did not impact operations.

Production was not affected by unplanned flaring. The flaring occurred due to surplus pressure on the plant's vapor recovery system.

An overnight power outage was due to a transformer failure in a substation. Operations were returned to normal the next day.

Flaring beyond permitted levels was reported from the FCCU in the east plant.

A crude leak from a pipeline within the refinery was contained. The leak occurred when a piece of equipment struck the line.

A malfunctioning FCCU was returned to operation on the afternoon of Sept. 30. The unit is expected to operate at a reduced rate for around two weeks while repairs are completed, the refiner said.

Brief maintenance was to be carried out at the No. 1 FCCU.

The refiner warned of planned flaring amid maintenance, which has been ongoing since early Sept.

An FCCU was taken offline for around one week of work.


CDU N.A. N.A. u 4-Oct-10


Hydrobon N.A. N.A. u 4-Oct-10

Sulfolane N.A. N.A. u 4-Oct-10

DIH N.A. N.A. u 4-Oct-10

*The rupture of a steam line in the east plant knocked offline a CDU, two diesel HTUs, a Hydrobon unit, a sulfolane unit, and a DIH unit. Excess emissions were also reported.





Description of labels

Region** Refiner City State Country Unit

Please note:All shutdown and restart dates are considered approximate.Shutdown and restart information is primarily derived from Reuters, Platts, and Bloomsberg newswire services.

Some capacities for "Unit size" and "Production impact" are not available or not applicable and are therefore designated "N.A."

Shutdown date

Restart date

Refinery capacity

World region

Date of shutdown

Date of restart

Operator of the refinery at which the shutdown took place

Location of refinery



The capacity of refinery in barrels per day

The type of problem encountered or the unit at which the problem was encountered

Refinery and unit capacity figures may be derived from primary source material (stated above) or from Oil and Gas Journal

When a filter is in place, the drop-down arrows and the numbers appear in blue. To unfilter the results, click on the drop-down menu, scroll to the top, and select the (All) option. This will un-filter the column.

Details Planned/unplanned

Shutdown and restart information is primarily derived from Reuters, Platts, and Bloomsberg newswire services.

Some capacities for "Unit size" and "Production impact" are not available or not applicable and are therefore designated "N.A."

Unit size, K b/d

Production impact, K b/d

The size of the unit affected in thousand barrels per day

The capacity impact of the shutdown in thousand barrels per day

Further details about the shutdown

Whether the shutdown was planned, symbolized by (p), or unplanned, symbolized by (u).

Refinery and unit capacity figures may be derived from primary source material (stated above) or from Oil and Gas Journal's annual Worldwide Refining Survey.

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copy of global refinery shutdown roundup sample

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