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Processing of challenged fractions and cracked co-feeds

A co-feed, feeding technology, applied in the field of defective distillate and cracked co-feed, which can solve the problem of low availability of deasphalting residue in bitumen commercial demand

Inactive Publication Date: 2019-07-02
EXXON RES & ENG CO
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Problems solved by technology

However, many types of deasphalted residues are unsuitable for bitumen production, and the commercial demand for bitumen is often significantly lower than the available quantities of deasphalted residues

Method used

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  • Processing of challenged fractions and cracked co-feeds
  • Processing of challenged fractions and cracked co-feeds
  • Processing of challenged fractions and cracked co-feeds

Examples

Experimental program
Comparison scheme
Effect test

Embodiment 1

[0167] Example 1 - Particle Removal

[0168] To demonstrate the effectiveness of settling for particle removal, steam cracker tar samples were settled for various lengths of time at various temperatures. A steam cracker tar feed or a feed comprising about 50% by weight steam cracker tar and about 50% by weight Exxon Mobil Aromatic 200 fluid was introduced into the settling tank. This latter mixture was used to investigate the effect of lower viscosity mixtures on the sedimentation rate. The feed is maintained in a settling tank at a temperature of about room temperature (~25°C), about 90°C, or about 115°C Figures 2 to 4 Settling time shown in . The steam cracker tar feed contained about 2200 wppm of particles having a particle size of 25 μm or larger.

[0169] figure 2 The settling rate of the steam cracker tar feed at 90°C and 115°C is shown. In the figure, the sedimentation rate curve corresponding to 115°C is indicated by an arrow. Such as figure 2 As shown in , i...

Embodiment 2

[0173] Example 2 - Fixed Bed Hydroprocessing of Catalytic Oil Slurry

[0174] Catalytic slurry from multiple FCC processes are mixed together to form a combined catalytic slurry feed. The combined catalytic slurry feed had a T10 distillation point of about 670°F (~354°C), a T50 of about 800°F (~427°C), and a T90 of about 1000°F (~538°C). The combined catalytic slurry feed contained about 12 wt% microcarbon, about 3 wt% sulfur, about 2500 wppm nitrogen content, and about 7.4 wt% hydrogen content. The combined catalytic oil slurry feed has about 1.12 g / cm 3 and contains about 10% by weight saturated hydrocarbons, about 70% by weight 4+ ring aromatics and about 20% by weight 1 to 3 ring aromatics. The combined catalytic oil slurry is also filtered to remove catalyst fines prior to treatment such that the resulting permeate has a total particle content of less than about 25 wppm. The filtered permeate formed from the combined catalytic slurry feed was hydrogenated in a fixed ...

Embodiment 3

[0178] Example 3 - Fixed Bed Hydroprocessing of Steam Cracker Tars

[0179] The steam cracker tar feed was hydrotreated under conditions similar to those from Example 2. The steam cracker tar feed has a T10 distillation point of about 420°F (-216°C), a T50 of about 680°F (-360°C) and a T90 of about 1300°F (-704°C). The blended feed contains about 22 wt% micro carbon, about 3.3 wt% sulfur, about 1100 wppm nitrogen content and about 1.16 g / cm 3 Density. The steam cracker tar feed is filtered to form a permeate having a total particle content of less than about 25 wppm. The permeate was treated with a supported mesoporous NiMo catalyst in a pilot plant similar to that used in Example 2. After 7 days of treatment, the pressure drop in the unit exceeded 100 psig (-0.7 MPag), making further treatment impractical. The catalyst in the reactor is fused together with the coke and must be drilled out of the reactor.

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Abstract

Systems and methods are provided for upgrading blends of catalytic slurry oil and steam cracker tar to form fuel and / or fuel blending products. The steam cracker tar can optionally correspond to a fluxed steam cracker tar that includes steam cracker gas oil and / or another type of gas oil or other diluent. It has been unexpectedly discovered that blends of catalytic slurry oil and steam cracker tarcan be hydroprocessed under fixed bed conditions while reducing or minimizing the amount of coke formation on the hydroprocessing catalyst and / or while reducing or minimizing plugging of the fixed bed, as would be conventionally expected during fixed bed processing of a feed containing a substantial portion of steam cracker tar. Additionally or alternately, it has been unexpectedly discovered that formation of coke fines within steam cracker tar can be reduced or minimized by blending steam cracker tar with catalytic slurry oil. This can facilitate fixed bed processing of the steam cracker tar, as after removal of particles the blend of catalytic slurry oil and steam cracker tar can maintain a reduced or minimized level of coke fines and / or other particles.

Description

technical field [0001] Systems and methods are provided for the hydroprocessing of blends of heavy aromatic fractions such as catalytic slurry fractions, steam cracker tar fractions, and / or deasphalting tower resid fractions. Background technique [0002] Fluid catalytic cracking (FCC) processes are commonly used in refineries as a means of converting feedstocks without the need for additional hydrogen to produce lower boiling fractions suitable for use as fuel. Although the FCC process can efficiently convert most of the usual input feeds, under normal operating conditions at least a portion of the resulting product can correspond to the fraction that leaves the process as a "bottoms" fraction. This bottoms fraction is typically a high boiling range fraction such as a ~650°F+ (~343°C+) fraction. Since this bottoms fraction may also contain FCC catalyst fines, this fraction is also sometimes referred to as a catalyst slurry. [0003] Steam cracking, also known as pyrolysis...

Claims

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Application Information

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Patent Type & Authority Applications(China)
IPC IPC(8): C10G67/04
CPCC10G45/08C10G45/20C10G67/00C10G67/02C10G67/0454C10G69/00C10G2300/1003C10G2300/107C10G2300/202C10G2300/207C10G2300/208C10G2300/301C10G2300/308B01D21/02B01J8/0278B03C5/02C10L1/04C10L2200/0438C10L2290/24C10L2290/38C10L2290/543C10L2290/547
Inventor 斯蒂芬·H·布朗布赖恩·A·坎宁安伦道夫·J·斯迈利萨米亚·伊利亚斯杰西·R·曼阿努斯阿尔德林·G·丘弗斯许腾格雷戈里·R·约翰逊约翰·P·格里利
Owner EXXON RES & ENG CO